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http://archive.org/details/annualreport1933onta
ABITIBI CANYON POWER DEVELOPMENT
Dam and power house from Canyon walls of taiirace.
The aggregate height of the structure from top of dam to normal tailwater level is about 250 feet.
Note the figures on the top of the power house roof.
/twenty-sixth Vnnual report
OF THE
HYDRO-ELECTRIC POWER
COMMISSION
OF THE
PROVINCE OF ONTARIO
FOR THE YEAR ENDED OCTOBER 31st
1933
PRINTED BY ORDER OF
THE LEGISLATIVE ASSEMBLY OF ONTARIO
ONTARIO
TORONTO
Printed and Published by Herbert H. Ball, Printer to the King's Most Excellent Majesty
1934
THE
HYDRO-ELECTRIC POWER COMMISSION
OF ONTARIO
Hon. J. R. Cooke, M.L.A Chairman
C. Alfred Maguire Commissioner
Rt. Hon. Arthur Meighen, P.C., K.C. . . Commissioner
W. W. Pope Secretary
F. A. Gaby, B.A.Sc, D.Sc Chief Engineer
LIBRARY
727496
UNIVERSITY OF TORONTO
To His Honour
The Honourable Herbert A. Bruce, R.A.M.C, M.D., F.R.C.S.,
Lieutenant-Governor of Ontario
May It Please Your Honour:
The undersigned has the honour to present to your Honour the Twenty-sixth
Annual Report of The Hydro-Electric Power Commission of Ontario for the fiscal
year ending October 31, 1933.
This Report covers all of the Commission's activities and also embodies
the financial statements, for the calendar year 1933, of the municipal electric
utilities operating in conjunction with the various systems of the Commission
and supplying electrical service to the citizens of the Province.
Dealing, as it does, with a multiplicity of activities relating to several
electrical systems obtaining power from thirty-nine hydro-electrical developments
operated by the Commission, supplemented by power purchased from other
sources, and recording financial and other data relating to the individual local
municipal electric utilities, the Annual Report presents a large amount of
statistical information, much of which must, of necessity, be of a summary
character.
The financial statements, the statistical data and the general information
given, however, are so arranged and presented as to give a comprehensive
survey of the Commission's operations. Not only does the Report record the
progress made during the past year, but it gives, in addition, certain cumulative
results for the various periods during which operation has been maintained
in the respective municipalities.
At the end of the fiscal year the number of municipalities served in Ontario
by the Commission was 757. This number included 27 cities, 96 towns, 269
villages and police villages and 365 townships. With the exception of 13
suburban sections of townships known as voted areas, the townships and 91
of the smaller villages are served as parts of 171 rural power districts.
Constructional Activities
During 1933 the chief item of constructional work was the completion
to its initial operating stage of the Abitibi Canyon development on Abitibi
[vj
vi TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
river. This work was carried out by the Commission for the Provincial
Government. A description of the development will be found in Section IV
of this Report.
Electrical construction work was confined chiefly to transformer stations
for the supply of electric power to a number of Paper Companies to enable them
to utilize secondary power in the generation of process steam. The Ontario
Paper (Steam) transformer station, Thorold, with a capacity of 67,500 kv-a.
in transformers and 90,000-kw. in electric steam generators, was installed and
placed in service on February 2, 1933. At the Great Lakes Paper (Steam)
transformer station Fort William two 8,000-kw. electric steam generators were
installed and placed in service on October 1, 1933. At Provincial Paper (Steam)
transformer station Port Arthur two 12,000-kv-a. transformers and two similar
capacity electric steam generators are being installed. Further installations of
a similar nature are under consideration.
Taking advantage of the relatively smaller amount of construction work
many improvements are being made to the stations and equipment on the various
systems.
Operating Conditions
The past year's operation of the systems has been satisfactory. Few inter-
ruptions to service occurred and failures of equipment were relatively few and
not serious in extent.
Rainfall was much below normal and seriously reduced the stream flow and
the capacity of the generating plants on the Eastern Ontario and Georgian Bay
systems. On the Georgian Bay system the reduction in generating capacity was
offset by an increased transfer of power from the Niagara system. On the
Eastern Ontario system the low stream flow during certain periods reduced the
capacity of all the generating stations on the Trent river to less than 40 per cent
of their normal maximum capacity. A severe power shortage would have been
experienced if a supplementary supply of reserve power had not been available
from the Gatineau Power Co. The Nipissing district also experienced a period
of low precipitation, but the storage works constructed by the Commission made
it possible for the stream flow to be maintained in volume adequate to supply
the demand for power.
The Commission has continued its efforts to protect the life and beauty of
trees along the public highways on which power lines are situated. The Commis-
sion's Forestry Division employs men especially trained for this work, which has
been carried out so as to protect the power lines and give reliable service without
seriously impairing the beauty of the trees. The Commission's efforts in this
respect have invoked many expressions of appreciation from highway and
municipal authorities.
Cost of Electrical Service Furnished by the Commission
The function of the Commission is not only to use its best endeavours to
provide for the people of Ontario an adequate and reliable supply of electrical
energy, but also to ensure that the cost of that electrical energy to the consumers
shall be the minimum consistent with the financial stability of the enterprise.
1934 HYDRO-ELECTRIC POWER COMMISSION vii
The success that has been attained in the accomplishment of the latter object
may be appreciated by a careful study of the actual rates to consumers as
presented in Statement "E," and of the statistical data setting forth the results
that have been attained for the consumers under these rates, as presented in
Statement "D," in conjunction with the various financial statements of the
Report.
The bill for retail service rendered, is the practical aspect of Hydro service
with which the average consumer is most concerned. It is, therefore, a
satisfaction to note that except in a very few cases the rates for service during
the period of depression have been maintained at their low levels or have been
made lower.
The knowledge that there are substantial reserves of power is a distinct
encouragement to the industrial organizations of the Province. Moreover, not-
withstanding the generous use made of electrical service by the domestic and
rural consumers in Ontario, there is still a large potential market for numbers
of electrical appliances which the low cost of electricity makes it economically
practicable to use.
Low Rates for Domestic Hot-Water Heating
The slackening in demand for power for industrial purposes has enabled
the Commission to encourage further use of power for domestic service. The
hot-water heater campaign inaugurated during the year 1933 has been successful
and incidentally has resulted in the development of better electric water-heating
equipment than was previously available. The heaters are installed without
capital cost to the consumer, but even at the low rates approved for their operation
the revenue obtained is usually sufficient to defray their initial cost in less than
a year. Thereafter their continued use results in increased revenue to the
municipal utilities and to the system. From the consumers' standpoint the
benefits of this service are greatly appreciated.
Load Conditions
The demand for power from the Commission's systems has increased during
the year, as shown by the table given below : —
October December October December
1932 1932 1933 1933
Niagara system, 25 cycle (Canadian loads
only) 816,505* 786,059 961,059 1,060,268
Other systems, total 239,438 251,898 311,038 379,778
Grand total (Canadian loads only) 1,055,943* 1,037,957 1,272,097 1,440,046
Note. — Power resold to the Gatineau Power Co. is included in the above table. The 1932 figures
which are affected are indicated by an asterisk.
Both this table and the table which follows are similar to the tables which
appeared in last year's Annual Report. In order to make the 1932 figures strictly
comparable with those of 1933 it has been necessary to include in October, 1932,
27,500 horsepower which was resold to the Gatineau Power Company in that
month. Further particulars regarding this change are given in the operating
section of the Report.
viii TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
The total Canadian loads during the months of October and December,
1933, were very much greater than the loads for the corresponding months of
1932. The greater part of the increase is in secondary power, the sale of which is
of advantage both to the Commission and to industry, so long as it can be
supplied. There is, however, an important though less pronounced increase in
the primary or firm load which occurred during the latter part of the year and
which has been persistently maintained over a considerable period in a way
which is most encouraging.
In last year's Report reference as made to the fact that the marked down-
ward trend of load in 1931 had been largely arrested, and that the decrease in
1932 was very slight. During December of 1932 and January of 1933, further
decreases occurred, but since April, 1933, the trend has been steadily upward.
By the end of the fiscal year, October 31, 1933, all ground lost during the first
part of the year had been regained, and the year closed with a net increase. This
gain for 1933 seems of special significance when compared with the losses of 1931
and 1932. The load losses of 1931 and 1932 have not yet been completely
regained, and the rate of increase for the firm load in 1933 is not as great as the
average rate of increase established over a long period of years prior to the
depression. Therefore, the effects of the industrial depression are still apparent
in the statistics for load during 1933, but after the sharper effects of the depression
in 1931 and 1932, it is encouraging to find that 1933 shows actual improvement.
The following tabulation corresponds to that given for several years in this
place in the Report, and shows the power supplied to the various systems at the
close of the fiscal and calendar years. The figures given show the total load of
each system and therefore include power exported as well as secondary power
and primary power. The figures given for the Niagara system do not correspond
to those shown in the table given above, as the first table covers Canadian load
only, exclusive of export, whereas the second table shows the total load including
export.
DISTRIBUTION OF POWER TO SYSTEMS
20-Minute Peak Horsepower
System Coincident Peak
October December October December
System 1932 1932 1933 1933
Niagara system 25 cycle. 867,446* 838,338 1,055,697 1,134,262
Dominion Power and Transmission system 43,968 48,525 45,710 51,743
Georgian Bay system 25,666 26,424 23,887 25,496
Eastern Ontario system 80,544 86,716 86,890 116,127
Thunder Bay system 65,700 63,800 90,450 120,000
Manitoulin rural power district 80 84
Northern Ontario Properties:
Sudbury district \ 177A1 in r 7 , / 12,466 12,802
Abitibi district / 17 ' 701 2U ' 5/0 \ 45,389 46,890
Nipissing district 3,751 3,799 3,539 3,901
Patricia district 2,048 2,058 2,627 2,735
Totals 1,106,884* 1,090,236 1,366,735 1,514,040
*\<>TE. — Power resold to the Gatineau Power Co. is included in the above table. The 1932 figures
which are affected are indicated by an asterisk.
1934 HYDRO-ELECTRIC POWER COMMISSION ix
Financial Summaries
The financial statements embodied in this Report are presented in two main
divisions, namely, a division — Section IX — which deals chiefly with the operations
of the Commission in the generation, transformation and transmission of electrical
energy to the co-operating municipalities; and a division — Section X — which
deals with the various operations of the municipal electric utilities in the localized
distribution of electrical energy to consumers. In Section IX, "Rural Operating"
reports are also given, which summarize the results of the local distribution of
rural electrical service by the Commission to the individual consumers in rural
power districts. This work is performed by the Commission on behalf of the
respective townships co-operating to provide rural service.
The cumulative results of the operation of the several systems of the
Commission as set forth in this Report demonstrate a sound financial condition.
Capital Investment
The total investment of the Hydro-Electric Power Commission of Ontario
in power undertakings and hydro-electric railways is $285,003,969.26, exclusive
of government grants in respect of construction of rural power districts' lines;
and the investment of the municipalities in distributing systems and other assets
is $109,657,573.64, making in power and hydro-electric railway undertakings a
total investment of $394,661,542.90.
The following statement shows the capital invested in the respective systems,
districts and municipal undertakings :
Niagara system $201,975,671 .41
Chats Falls development 6,167,756.08
Georgian Bay system 8,394,645 . 25
Eastern Ontario system 19,372,833 . 44
Thunder Bay system 18,630,772 . 18
Manitoulin rural power district 32,625 .79
Northern Ontario properties 23,790,137.37
Hydro-Electric railways 2,076,924 . 94
Office and service buildings, construction plant, inventories, etc 4,562,602.80
$285,003,969.26
Municipalities distributing systems and other assets (exclusive of $26,045,679.00
of municipal sinking fund equity in H.E.P.C. system) — all systems 109,657,573 .64
$394,661,542.90
Revenue of Commission
The revenue of the Commission derivable from the municipal utilities
operating under cost contracts and from other customers with whom — on behalf
of the municipalities — the Commission has special contracts, all within the
x TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
Niagara, Georgian Bay, Eastern Ontario and Thunder Bay systems, Manitoulin
rural power district and Northern Ontario properties, aggregates $27,520,853.79.
The following statement shows how this revenue has been appropriated:
Revenue from municipal electric utilities and other power customers $27,520,853.79
Operation, maintenance, administration, interest and other
current expenses $27,275,570 . 17
Reserves for sinking fund, renewals, contingencies and obsoles-
cence provided in the year. 4,839,838 . 70
$32,115,408.87
Less: Appropriated from obsolescence and contingencies reserves 4,236,606.73
27,878,802.14
Net balance charged to municipalities under cost contracts $357,948.35
In connection with the foregoing statement it should be noted that, in
making its annual determinations of costs chargeable for power supplied to the
participating municipalities, the Commission for many years has followed a
policy which recognizes the desirability of stabilizing the costs per horsepower
one year with another. Commencing with 1926 and continuing to 1930, there
were included in the amounts set aside to the reserve for obsolescence and
contingencies, additional sums designed to care for possible lean years that might
come in the future. A proportion of these extra reserves was derived from the
profitable employment of system reserve generating equipment. In 1933 the
contingency reserve was drawn upon in the case of the Niagara system to the
extent of $4,236,606.73. This relief was given to the municipalities in their cost
of power to compensate for the increased costs and reduced revenues in the year.
In all other respects the various reserves have continued to be accumulated on
the same basis as formerly, with the result that in the aggregate the reserves
of the Commission show a net increase for 1933 of $3,290,453.57 as compared
with the totals at the end of 1932.
Rural Electrical Service
During the past few years very substantial progress has been made in
Ontario in the field of rural electrification. Practically all rural electrical
service is now given through rural power districts which are operated directly
by the Commission. There is now rather more than $17,690,000 invested in
the rural power district systems established by the Commission. Towards
this rural work the Ontario Government, pursuant to its policy of promoting
the basic industry of agriculture, has, in the form of grants-in-aid, contributed
50 per cent of the costs of transmission lines and equipment, or some $8,750,000.
A total of 9,244 miles of transmission lines have been constructed to date, of
which 326 miles were constructed during the past year. There are now about
62,000 customers supplied in the rural power districts.
934
HYDRO-ELECTRIC POWER COMMISSION
XI
RURAL
POWER E
USTRICT
S— OPER/
lTIONS FOR THE
YEAR 1933
Niagara
system
Georgian
Bay
system
Eastern
Ontario
system
Thunder
Bay
system
Mani-
toulin
rur. power
district
Nor. Ont.
Nipissing
district
Totals
Cost of power as
provided to be
pai d under
Power Commis-
sion Act
Cost of operation,
maintenance
and administra-
tion
$ c.
810,110.29
557,105.44
294,442.54
251,397.57
125,698.79
66,871.35
$ c.
107,127.66
56,844.72
36,600.19
28,890.44
28,890.44
7,986.56
$ c.
193,481.31
121,212.84
77,164.46
62,925.98
31,462.99
16,863.37
$ c.
3,591.41
3,509.95
2,307.24
1,738.59
869.29
457.68
$ c.
3,281.25
1,447.26
1,434.09
996.29
476.90
285.45
$ c.
4,115.38
2,818.63
926.80
723.40
361.70
194.22
$ c.
1,121,707.30
742,938.84
Interest
412,875.32
Renewals
Obsolescence and
contingencies . .
Sinking fund ....
346,672.27
187,760.11
92,658.63
Total expenses. . .
Revenue from
customers
2,105,625.98
2,063,370.73
266,340.01
236,399.48
503,110.95
470,228.73
12,474.16
9,275.86
7,921.24
6,537.40
9,140.13
10,211.29
2,904,612.47
2,796,023.49
Net surplus, all
districts
1,071.16
1,071.16
Net deficit, all
districts
42,255.25
29,940.53
32,882.22
3,198.30
1,383.84
109,660.14
Net deficit, all
systems
108,588.98
As indicative of the steady progress being made by co-operative effort
between the Commission and the rural consumers in reducing the cost of electrical
service, it may be stated that whereas in 1929, 7,700 consumers were being served
in 13 rural power districts in which the primary rate was 3 cents per kilowatt-
hour; in 1933 more than 21,000 consumers in 23 rural power districts were enjoying
a primary rate of 3 cents or less per kilowatt-hour. During the same period the
number of consumers in rural power districts where the highest primary rate of
8 cents per kilowatt-hour was in force had diminished, notwithstanding the
number of new districts in operation. Most of the consumers in the districts
where the primary rate was 3 cents or less per kilowatt-hour had a follow-up rate
of 1.5 cents or less per kilowatt-hour, while even the consumers in the districts
where the primary rates were highest obtained additional energy over the
reasonable class demand minimum at a rate of 2.0 cents per kilowatt-hour. All
these rates are, of course, subject to the prompt payment discount of 10 per cent.
Municipal Electric Utilities
The following is a summation of the year's operation of the local electric
utilities conducted by municipalities receiving power under cost contracts with
the Commission:
Total revenue collected bv the municipal electric utilities $30,627,841 .88
Cost of power. $19,330,861 .58
Operation, maintenance and administration 5,189,385.78
Interest 2,426,286.35
Sinking fund and principal payment on debentures 2,319,319.09
29,265,852.80
Amount available and set aside for depreciation and other reserve purposes $1,361,989.08
xii TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
The setting-up of the reserves on rates customarily adopted in the past
would have required an amount of $1,989,000.41, which is $627,011.33 in excess of
the amount shown in the foregoing table as available for the present year.
In this connection it is important to note that the municipal Hydro utilities
provide for the retirement of their capital liabilities by either the instalment
or sinking-fund method, and such payments are treated as part of the cost of
the service.
Reserves of Commission and Municipal Electric Utilities
The total reserves of the Commission and the municipal electric utilities
for sinking fund, renewals, contingencies and insurance purposes amount to
$129,172,759.94 made up as follows:
Niagara system $52,380,601 . 09
Georgian Bay system 2,822,302 . 39
Eastern Ontario system 5,338,1 15 . 82
Thunder Bay system. . . 3,104,669.25
Northern Ontario properties 625,282 . 56
Nipissing rural power districts and Manitoulin rural power district 7,559.71
Service building and equipment 706,848 . 99
Bonnechere storage 3,536 . 97
Hydro-Electric Railways (Guelph) 121,481 . 78
Insurance, workmen's compensation and staff pensions 4,322,861 .69
Total reserves of the Commission $69,433,260 . 25
Total reserves of municipal electric utilities 59,736,819.76
Total Commission and municipal reserves $129,170,080 .01
As has been commented above in connection with the statement of revenues,
the total reserves of the Commission increased in 1933 by $3,287,773.64 over the
total for 1932, which was $66,145,486.61. The fact that the net increase in
total reserves was, in 1933, less than in some former years, reflects the advan-
tageous working out of the Commission's policy of cost stabilization, under
which withdrawals were made in 1933 from special reserves provided out of
revenues of earlier years for that purpose. The net increase in the total of
Commission and municipal reserves for the year was $6,399,976.10.
The consolidated balance sheet of the municipal electric utilities, on page
288, shows a total cash balance of $1,696,489.24, and bonds and other invest-
ments of $2,163,785.20. The total surplus in the municipal books now amounts
to $41,612,778.64 in addition to depreciation and sundry other reserves
aggregating $18,124,041.12 ; these two amounts making the total of $59,736,819.76
shown in the above table.
The following is a brief summary of the principal operations relating to
the several systems of the Commission :
Niagara System
The Niagara system embraces all territory lying between Niagara Falls,
Hamilton and Toronto on the east and Windsor, Sarnia and Goderich on the
west served with electrical energy generated at plants on the Niagara and Ottawa
rivers, supplemented with purchased power transmitted from plants on the
Niagara, Gatineau, St. Lawrence, Ottawa and Lievre rivers. A few munici-
1934 HYDRO-ELECTRIC POWER COMMISSION xiii
palities and districts of the Niagara system are served also with power developed
at DeCew Falls near St. Catharines.
Arrangements for .progressive delivery of increased quantities of power,
made some years ago, will furnish power supplies for this system, which, with a
moderately rapid return to normal business conditions, should be adequate for
the immediate future. In addition to power contracted for with the Gatineau
Power Company, and power obtained from the development at Chats Falls
which provides the Commission with 192,000 horsepower, the Commission holds
contracts for the delivery of additional power, amounting eventually to 250,000
horsepower, to be developed on the St. Lawrence river by the Beauharnois Light,
Heat & Power Company, and 125,000 horsepower to be delivered to the Com-
mission as required from a plant on the Lievre river under a contract with the
James MacLaren Company, Limited, subsequently assigned to a subsidiary power
company known as MacLaren-Quebec Power Company. The first block of
20,000 horsepower to be taken under the contract with the MacLaren-Quebec
Power Company was taken July 1, 1933, and the second block of power to be
taken from the Beauharnois Light, Heat & Power Company, amounting to
40,000 horsepower, was taken October 1, 1933.
The total capital invested by the Commission on behalf of the co-operating
municipalities of the Niagara system amounts to $208,143,427.49. This amount
includes the investment in the power properties purchased from the Dominion
Power and Transmission Company (which have been merged with, and now form
part of the Niagara system), also the Commission's share of the generating plant
at Chats Falls, together with the transformer and switching stations at that
point and the transmission lines from the Ottawa river to the Niagara system.
The accumulated reserves for renewals, obsolescence, contingencies and sinking
fund, aggregate $52,380,601.09.
From the rural power districts of this system, which are directly operated
by the Commission, the revenue received for the year from customers was
$2,063,70.73, and the total cost of supplying the service was $2,105,625.98,
leaving a balance of $42,255.25, which has been charged to the districts in this
system.
With respect to the electric utilities of the various urban municipalities of
the Niagara system, the cost of power, as adjusted by the Commission at the
close of the year was $246,061.75 more than the total amount collected at the
interim rates and this sum has been charged to the municipal utilities. The
total revenue of the municipal electric utilities served by this system was
$25,024,438.69.
After meeting all expenses in respect of operation — including interest — setting
up the usual standard depreciation reserve (which amounted to $1,604,015.63)
and providing $2,108,108.41 for the retirement of instalment and sinking-fund
debentures, the total net shortage for the year for the municipal electric utilities
served by the Niagara system amounted to $652,392.31.
Georgian Bay System
The territory served by the Georgian Bay system includes that portion of
the Province adjacent to Georgian bay and lake Simcoe. The area extends
Errata — The total reserves in text of page xii should be
the same as the totalled details, namely, $129,170,080.01.
The revenue figure in third paragraph on page xiii should
be $2,063,370.73 as on page xi.
The figure of net increase in next to last line of second
paragraph on pagex should be $3,287,773.64 as shown in third
paragraph of page xii.
xiv TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
from Huntsville in the north to Port Perry in the southeast, and on the west
and north it is bounded by lake Huron and Georgian bay. It thus takes in the
counties of Bruce, Grey, Dufferin, and Simcoe, and the northern portions of the
counties of Huron, Wellington and Ontario, as well as a large portion of the
district of Muskoka. The territory served by this system lies immediately north
of the Niagara system and west of the Eastern Ontario system.
During the year the distribution system purchased from The Mildmay
Electric Company in the village of Mildmay, was sold to the Corporation and a
cost contract executed with the latter for a supply of power under the Power
Commission Act. The property purchased from The Formosa Electric Light
Company last year was reconstructed and merged into the Bruce rural power
district.
Electrical energy for the Georgian Bay system is obtained from eleven
hydro-electric generating plants at South Falls, Hanna Chute, and Trethewey
Falls on the south branch of the Muskoka river, at Bala on the Muskoka river,
at Wasdells Falls and Big Chute on the Severn river, at Eugenia Falls on the
Beaver river, and at Hanover, Walkerton and Southampton on the Saugeen
river. The output of these generating plants is supplemented by the purchase of
power from the Niagara system, delivered through frequency changer equipment
at Hanover and Mount Forest.
Load conditions in the various municipalities of the system remained
practically constant throughout the year in comparison with previous year
conditions, although some new load was secured in one of the municipalities during
the latter part of the year. The power supplied to summer resort districts forms
an important part of the Georgian Bay system load, and the peak demand of this
class of business was considerably greater than during last year, although it dees
not show up in the yearly average due to the fact that it is all supplied during
the summer months only.
The lack of rainfall during the summer and fall months of the year seriously
affected the stream flow of the rivers on which the various developments are
situated, necessitating the purchase of a larger block of power from the Niagara
system, than was purchased last year.
The total capital invested by the Commission on behalf of the co-operating
municipalities in the Georgian Bay system is $8,394,645.25 and the accumulated
reserves for renewals, obsolescence, contingencies, and sinking fund aggregate
$2,822,302.39.
The revenue received from consumers in the rural power districts of this
system directly operated by the Commission was $236,399.48 and the total cost
of supplying service to same was $266,340.01, leaving a balance of $29,940.53
to be charged to these districts, as detailed under financial statements in Section
IX of this Report.
The actual cost of power supplied by the Commission during the year to
the electric utilities of the various urban municipalities of the Georgian Bay
system served under cost contracts was $55,972.57 less than the total collections
under the interim rates. This sum has been credited to the various municipalities
directly affected. The total revenue of the municipal electric utilities served by
this system was $1,135,255.35, a decrease of $18,366.96 as compared with the
previous year.
1934 HYDRO-ELECTRIC POWER COMMISSION xy
After meeting all operating expenses and fixed charges, including interest,
and the standard depreciation reserve amounting to $71,460.00, as well as pro-
viding $59,232.44 for the retirement of instalment and sinking fund debentures,
the combined municipalelectric utilities of the Georgian Bay system show a net
loss for the year of $2,454.88.
Eastern Ontario System
This system serves that part of Ontario lying east of the areas served by
the Georgian Bay and Niagara systems. The districts included are the Central
Ontario, St. Lawrence, Rideau, Ottawa and Madawaska.
Power is supplied from developments owned by the Commission on the
Trent Canal system, the Mississippi and Madawaska rivers. Power is purchased
from the Gatineau Power Company, the Rideau Power Co. and the Beach Estate
at Iroquois. The Cedar Rapids Transmission Company has also been supplying
power to the Commission during the year but notice was given of cancellation of
this contract on December 31, 1932. No other major changes were made in
generation or transmission facilities during the year.
All the municipal distribution properties forming part of the old Electric
Power Company properties have now been sold to the municipalities concerned,
with the exception of the plants in Millbrook, Newburgh, Newcastle and Orono
and the gas plant in Cobourg. The municipality of Orono has entered into
negotiations with this Commission for the purchase of the local distribution
system.
While the power demands of this system are somewhat less than last year,
the amount of purchased power from the Gatineau Power Company and other
private companies has been very necessary owing to the shortage of power
occasioned by the low water on the Trent river.
The total capital invested by the Commission on behalf of the co-operating
municipalities amounts to $19,372,833.44 and the accumulated reserves for
renewals, obsolescence, contingencies and sinking fund aggregate $5,338,115.82.
The rural power districts of this system, which are directly operated by
the Commission, show the revenue received for the year from customers as
$470,228.73 and the total cost of supplying service to be $503,110.95, leaving a
balance of $32,882.22, which was charged to the districts in this system.
With respect to the electric utilities of the various urban municipalities of
the Eastern Ontario system operating under cost contracts, the actual cost of
power supplied by the Commission during the year was $35,131.42 less than the
total amount collected at the interim rates and this has been credited to the
municipal utilities. The total revenue of the municipal electric utilities served
by this system was $3,142,850.15, a decrease of $35,906.10
After meeting all expenses in respect of operation — including interest —
setting up the usual standard depreciation reserve (which amounted to
$176,758.10) and providing $130,523.35 for the retirement of instalment and
sinking-fund debentures, the total net surplus for the year for the municipal
electric utilities served by the Eastern Ontario system amounted to $82,632.61.
xvi TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
Thunder Bay System
The territory served by the Thunder Bay system lies wholly within the
district of Thunder Bay, practically all of the power being utilized by the cities
of Port Arthur and Fort William, and the rural sections immediately adjacent
thereto, and by the village of Nipigon.
Power is obtained from two hydro-electric developments on the Nipigon
river, one at Cameron Falls and one at Alexander, and, in addition to supplying
the domestic and commercial requirements of the municipalities mentioned, is
used largely by the pulp and paper industry and the grain trade. A marked
improvement has taken place in the load supplied on this system, especially
during the latter portion of the year, due principally to the increased production
by the pulp and paper mills, and also to an extensive use of secondary power
sold on an "at-will" basis for the generation of process steam. Contracts already
negotiated for the latter class of load, plus power sold on a firm power basis,
will, during the coming year, require the entire generating plant capacity of the
two developments serving this system. The total investment of the Commission
in the Thunder Bay system is $18,630,772.18, and the accumulated reserves for
renewals, contingencies and sinking fund amount to $3,104,669.25.
From the rural power districts of this system, which are operated directly
by the Commission, the revenue received for the year from customers was
$9,275.86, and the total cost of supplying the service was $12,474.16, leaving a
balance of $3,198.30, which has been charged to the districts in this system.
The cost of power supplied by this system during the year was $95,683.25 in
excess of revenue obtained from the interim monthly billing. This represents a
substantial improvement over last year's conditions. A much better showing
will be made during the next year when the new contracts previously referred to
will be in operation for the full twelve months of the year. The total revenue
of the municipal electric utilities in this system was $1,325,297.69. The munici-
palities served by this system operated with a net loss of $54,796.75 after meeting
all operating expenses — including interest — and setting up the standard deprecia-
tion reserve amounting to $42,481.14 and providing $21,454.89 for the retirement
of installment and sinking fund debentures.
Manitoulin Rural Power District
This rural power district supplies electrical service to the area surrounding
the town of Gore Bay and the hamlet of Mindemoya. Other sections of Mani-
toulin island, including the town of Little Current, the village of Manitowaning
and the hamlet of Shequiandah and adjacent areas, have also made application
for service, and various meetings were held for the purpose of submitting informa-
tion to the communities mentioned. A complete investigation was made with
respect to extending lines, and obtaining a supply of power from an additional
source for this new load.
At the present time the district is supplied with power purchased from the
Kagawong development of the Little Rapids Pulp Company.
1934 HYDRO-ELECTRIC POWER COMMISSION xvii
Northern Ontario Properties
The area in which are situated the Northern Ontario Properties comprises the
entire portion of the Province lying north of lake Nipissing and French river
areas, and west of the Quebec boundary, exclusive of the territory served by the
Thunder Bay system. The active districts in which power is actually being
delivered by the Commission include North Bay and the vicinity, in the district
of Nipissing; Sudbury, and the vicinity in the district of Sudbury; Iroquois Falls
in the district of Cochrane, and the Red Lake mining camp in the district of
Patricia. These various districts are being served under a direct agreement with
the Government of the Province. They are not interconnected, and are served
under entirely different conditions than those prevailing in the southern and
eastern portions of the Province. Many sections in the northern part of the
Province are served by independent municipal utilities, and the Commission,
during the year, has, upon request, given engineering advice and assistance
concerning the operation and maintenance of the local systems, to many of
these utilities.
Nipissing District
The area served in this district includes the city of North Bay, the town of
Powassan and the unincorporated hamlets of Callander and Nipissing and
portions of the townships of Ferris, Himsworth, Nipissing and Widdifield.
Power is obtained from hydro-electric developments at Nipissing, Bingham
Chute and Elliott Chute on the South river, supplemented when necessary by
purchased power from the Abitibi Power and Paper Company's development at
Crystal Falls on the Sturgeon river.
Very little change occurred in the demands of this district throughout the
year, compared with the previous year; consequently, no generating plant,
transformation or transmission changes other than those of a routine nature were
required.
Sudbury District
This district includes the area adjacent to the city of Sudbury which is
served at 60 cycles from three power developments on the Wanapitei river.
Power is supplied for municipal and lighting purposes to the city of Sudbury, and
to large mining companies in the Sudbury basin. A substantial increase in load
has taken place on this system during the year, due to one of the large mining
companies having increased its demand by approximately 50 per cent, in conse-
quence of which the plant capacity of the developments is completely sold, and
any further load expansion will have to be taken care of at 25 cycles from the
Abitibi Canyon transmission line system, or by t^e installation of frequency
changer sets for transformation from 25 to 60 cycles.
Abitibi District
This district embraces that section of the Province within transmission
distance of the Abitibi Canyon development and includes the mining areas
adjacent to Sudbury, Timmins and Kirkland Lake. During the year the Com-
mission assumed, on behalf of the Government of the Province, the operation of
the Abitibi Canyon development and transmission line system formerly the
property of The Ontario Power Service Corporation Limited. Power is being
supplied at the present time to a large mining industry at Copper Cliff and nego-
xviii TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
tiations have been carried on with a number of mining companies in the Porcupine,
Kirkland Lake and Swayze camps, and it is anticipated that a number of these
companies will be supplied during the coming year. A contract was completed
with The Canada Northern Power Corporation for supplying all of the future
load growth of this company for a term of ten years.
Patricia District
This district comprises the territory included in that portion of the Province
lying within the geographical area bearing the same name. At the present time
the Commission in this district is operating one power development only. It is
situated at the foot of Lac Seul on the English river and power is being supplied
to a large gold mine in the Red Lake mining camp. Power is available for any
other mining property within transmission distance of this development. A
large increase in the load on this development has taken place during the year,
due to the mining company served having substantially increased its milling
capacity. The total load, averaged over the year, shows an increase of 3 per cent,
but the load during the latter part of the year was gradually increasing. The
peak load, occurring in October, shows an increase of 28 per cent over the previous
year.
A survey was made and an estimate prepared in connection with a develop-
ment on the Albany river at the foot of lake Joseph for two other mining properties
in the Patricia district. It is expected that contracts will be closed early next
year, and arrangements made to proceed with the construction of this
development.
The Annual Report
The Table of Contents, pages xxv and xxvi, conveys a good understanding
of the scope of the matters dealt with in the Report, to which there is also a
comprehensive Index. To those not conversant with the Commission's Reports
the following notes will be useful.
In Section II, pages 5 to 60. dealing with the Operation of the Systems,
are a number of interesting diagrams showing, graphically, the monthly loads
on the various systems. Tables are also presented showing the amounts of
power taken by the various municipalities in October during the past three years.
The rural distribution work of the Commission has proved of widespread
interest and special reference to this is made in Section III, on pages 69 to 88.
The power distributed to rural districts is, and possibly must always be, but
a relatively small proportion of the power distributed by the Commission. The
supplying of electrical service in rural areas, and especially on the farm, has,
however, been of great economic benefit to Ontario. The Provincial Government
grants-in-aid of the capital cost of this work have been of value to agricultural
activities, and have assisted the Commission to extend rural transmission lines
to many areas.
In Sections IV, V and VI will be found information respecting progress of
work on new power developments and on transmission system extensions,
together with photographic illustrations.
About one-half of the Report is devoted to financial and other statistical
data which are presented in two Sections, IX and X.
1934 HYDRO-ELECTRIC POWER COMMISSION xix
Section IX presents in summary form the financial statements relating to
the operations of the Commission chiefly in the generation, transformation and
transmission of electrical energy to the co-operating municipalities. It is
introduced by an important explanatory statement which appears on pages
133 to 137, to which special reference should be made.
Section X presents in summary form the financial statements relating to
the operations of the municipalities in the localized distribution of electrical
energy to consumers. It also contains details of the costs of electrical energy to
consumers in the various municipalities and tabular statements of the rates in
force which have produced these costs. An explanation of the various tables
and statements is given at the commencement of this Section on pages 281 to 283,
and a special introduction to Statement "D," which relates to the cost of
electrical service in Ontario, together with a diagram, appears on pages 406 to 409.
In its Annual Reports the Commission aims to present a comprehensive
statement respecting the activities of the whole undertaking under its
administration. Explanatory statements descriptive of the operations of the
Commission in various branches of its work are suitably placed throughout
the Report in order that the citizens of the Province may be kept fully
informed upon the working-out of the Commission's policies.
The Commission receives many letters asking for general information
respecting its activities, as well as requests for specific information concerning
certain phases of its operations. In most cases these enquiries can satisfactorily
be answered by simply directing attention to information presented in the
Annual Report of the Commission. Real benefit would result to the ''Hydro"
undertaking if those who are commenting upon aspects of the Commission's
work would first make sure by consulting the Commission's publications that
the data upon which their comments are to be based are adequate and pertinent
to the subject in hand. By such a course much misrepresentation, as well as
inconvenience, would be avoided.
In closing this summary of the record of Hydro's progress during the past
year, and at a time when we are emerging from a period of exceptional economic
stress, it is especially fitting to acknowledge the devotion and efficiency that
characterize the services rendered by the Commission's staffs. Unquestionably,
in both good times and bad times, the municipall^owned Hydro undertaking
owes in great measure its outstanding success to the unremitting and competent
efforts of the professional and other employees of the Commission and of the
municipal utilities, directed as such efforts are towards the constant improvement
of the technical operations of the undertaking. The Commission, as trustee
charged with providing electrical service for Ontario citizens at minimum costs,
has not given its employees remuneration as large as is paid by comparable
privately-owned electrical utilities elsewhere, but the Commission has felt that
the least it could do in appreciation of the loyalty of its employees was to give
them assurance that their security of employment was not subject to arbitrary
disturbance. Moreover, continuity of service by a competent staff — a source
of strength to any business organization — is, in the case of the Commission's
xx TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
undertaking with its many unique features and its principle of service at cost,
especially necessary. With these considerations in mind, the Commission some
years ago established a system of contributory pensions, under which the
permanent employees deposit with the Commission sums, which the Commis-
sion supplements, in order that the employees may have security in old age after
a lifetime of faithful service.
The harmonious relations that have always existed between the Commission
and its staff have been greatly promoted by the attitude taken by successive
Provincial governments toward maintaining the independence of administration
of the Commission as a business enterprise operated in trust for the municipalities.
The basic principles established by the founders of the undertaking, and incor-
porated in the Power Commission Act, give the Commission sole jurisdiction
over appointments of staff and all other details of operation, and limit govern-
ment participation in the municipal undertaking to approval of such matters
as capital expenditures and power contracts determined by the Commission to
be required in the interests of the municipalities.
It is a matter of sincere satisfaction to me, speaking after more than a decade
of service as Commissioner, and, latterly, as Chairman, to be able to affirm
categorically that at no time in my term of office has any Ontario Government
gone beyond the limits of jurisdiction assigned to it by the Power Commission
Act as appropriate to its function of banker for the municipalities. There has
been no suggestion of interference with appointments of employees or other
matters that are in the exclusive jurisdiction of the Commission. Moreover,
every capital expenditure and every power commitment on behalf of munici-
palities has been made at the instance of the Commission having regard only
to the interests of the municipalities, and the Government's participation in
such matters has been confined to scrutinizing and approving the Commission's
proposals, and assisting in inter-governmental negotiations where necessary.
The readiness of successive Governments to co-operate has been of notable
value to the undertaking; in the case of rural service the Governmental financial
contribution is a factor without which the remarkable expansion in service in
recent years could not have been achieved. I am constrained to record these
observations here because of the fact that statements intimating the contrary
have been publicly but unjustifiably made.
The co-operation manifested by the Press in giving space and services to
inform the citizens of Ontario on matters relating to the Commission's work is
a valuable safeguard to the welfare of the Hydro undertaking, and the Com-
mission desires again to record its special appreciation of the public-spirited
support accorded to its efforts.
Confirming the Commission's announcement, made early in the present
year, of its expectation of an improvement in the general adverse conditions
against which the Hydro undertaking has had to contend for the last three or
four years, it is a gratification to be able, at the time of writing, to state that
results thus far evident for 1934 are showing a very substantial betterment
over the results for corresponding periods of 1933. The large increases in electrical
demands and in revenues that are being experienced afford excellent encourage-
1934 HYDRO-ELECTRIC POWER COMMISSION xxi
ment. The Commission is confident that, with continuation of present trends,
the results of operation of the Hydro undertaking in the next two or three years
will furnish complete vindication of the wisdom of the actions it has taken with
respect to providing power supplies adequate for the requirements in the early
future of the municipalities and industries.
Respectfully submitted,
J. R. Cooke,
Chairman.
1934 HYDRO-ELECTRIC POWER COMMISSION xxiii
Toronto, Ontario, March 31st, 1934.
Hon. J. R. Ccoke, M.L.A.,
Chairman, The Hydro-Electric Power Commission of Ontario,
Toronto, Ontario.
Sir, — I have the honour to transmit herewith the Twenty-sixth Annual
Report of The Hydro-Electric Power Commission of Ontario for the fiscal year
ended October 31st, 1933.
I have the honour to be,
Sir,
Your obedient servant,
W. W. Pope,
Secretary
934 HYDRO-ELECTRIC POWER COMMISSION xxv
CONTENTS
Section page
I. Legal Proceedings:
Acts (see also Appendix I) ------------ l
Right-of-way --------------- 2
II. Operation of the Systems:
General -5
Niagara system 14
Georgian Bay system 29
Eastern Ontario system - 36
Thunder Bay system - 48
Northern Ontario properties 52
III. Municipal Work:
Niagara system 61
Georgian Bay system 64
Eastern Ontario system - - 65
Thunder Bay system 66
Northern Ontario properties - - - - 67
Rural Electrical Service 69
IV. Hydraulic Engineering and Construction:
General 89
Niagara system 90
Georgian Bay system - 91
Northern Ontario properties 92
Hydraulic investigations - 96
Electrical Engineering and Construction:
♦
Niagara system 99
Georgian Bay system 102
Eastern Ontario system ----- 104
Thunder Bay system - 104
Northern Ontario properties 106
VI. Transmission, Distribution and Rural systems (see also Appendices II and III):
Niagara system 107
Georgian Bay system 108
Eastern Ontario system - - 108
Thunder Bay system 108
Telephone lines — all systems - - - - - - - - - - 110
Distribution lines and systems - - - - - - - - - - 110
xxvi TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
Section page
VII. Laboratories 113
Electricai Inspection - 125
VIII. Electric Railways:
Sandwich, Windsor and Amherstburg railway ------- 128
guelph district railway - 130
IX. Financial Statements re Hydro-Electric Power Commission:
Explanatory statement respecting the accounts - 133
General detailed statement of assets and liabilities 138
Niagara system 154
Georgian Bay system 212
Eastern Ontario system 234
Thunder Bay system 258
Provincial Treasurer, account with 264
Northern Ontario properties 266
Guelph Radial railway 272
Hamilton Street railway 274
Appropriations, advances and capital expenditures 276
X. Municipal Accounts and Statistical Data:
Explanatory statement 281
Consolidated balance sheet 284
Consolidating operating report 289
Statement A — Balance sheets 294
Statement B — Detailed operating reports 340
Statement C — Respecting street lights - 387
Statement D — Comparative revenue, consumption, number of consumers,
AVERAGE MONTHLY BILL, NET COST PER KILOWATT-HOUR, ETC. - - - 406
Statement E — Cost of power to municipalities and rates to consumers for
DOMESTIC, COMMERCIAL LIGHTING AND POWER SERVICE 424
Appendix I. Acts -. 441
Appendix II. Transmission Line Records 445
Appendix III. Distributing Lines and Systems 468
Index 475
1934 HYDRO-ELECTRIC POWER COMMISSION
ILLUSTRATIONS
PAGE
Abitibi Canyon Power Development ---------- Frontispiece
Forestry Division — Operating Department:
Diseased trees a menace ------------- 1 j
Crown and side pruning - - - - - - - - - - - - - -13
Rural Electrical Service in Ontario:
Cheese factory utilising electric power - - - - - - - - -69
a farm home in ontario using hydro service 70
Suggested set-up of utility-motor chopper in barn - - - - - - -74
mllk cooling by electric refrigeration with agitation 75
Electric soil heating 79
Three-horsepower motor driving machinery in barn - 80
Application of electric drive to water pumping 81
Walkerton Dam — Saugeen River ------------ 91
Abitibi Canyon Power Development — Abitibi River:
forebay, dam and sluice-gate ------------ 92
High-water channel - - -93
Tailrace from power house -93
Kagami Falls — Albany River - 97
Electric Steam Generators — Ontario Paper Company 101
Transformer Station — Ontario Paper Company - - 103
Transformer Station at Cameron Falls — Nipigon River - 105
Hydro 220,000-Volt Transmission Lines:
Transposition towers, Beauharnois-Chats Falls Line* - - - - - - 109
Semi-anchor tower -------- 109
Suspension tower --------------- 309
Testing and Research Laboratories:
Field inspection of concrete structures - - - 115
Apparatus for measuring the gloss of paints - - - 117
Endurance test on thermostats - - - - - 119
Laboratory for testing insulated wire conductors - - 120
Brake TESTS on small motors - - - - 121
Temperature and overload tests on fuses - 121
Endurance tests on three-heat range switches - - - - "- - - 124
xxviii TWENTY-SIXTH ANNUAL REPORT No. 26
DIAGRAMS
PAGE
Niagara system — Peak loads, 1910 to 193? ---------- 16
Niagara system — Total kilowatt-hour load, 1919 to 1933 ------ \g
Dominion Power and Transmission system — Diagram of stations ----- 23
Niagara system — Diagram of stations. Insert facing ------- 24
Georgian Bay system — Peak loads, 1919 to 1933 --------- 31
Georgian Bay system — Diagram of stations. Insert facing ------ 32
Eastern Ontario system — Peak loads for all districts ------- 37
Precipitation diagram — Otonabee watershed -------- 38
Central Ontario district — General operating data ------- 39
Ottawa district — Peak loads, 1917 to 1933 --------- 43
Madawaska district — Diagram of stations --------- 44
Eastern Ontario system — Diagram of stations. Insert facing ----- 44
Thunder Bay system — Peak loads, 1921 to 1933 --------- 49
Thunder Bay system — Diagram of stations ----- 51
Northern Ontario Properties — Diagram of stations -------- 53
Nipissing district— Peak loads, 1921 to 1933 -------- 52
Sudbury district — Peak loads, 1930 to 1933 --------- 55
Abitibi district — Peak loads, 1931 TO 1933 --------- 57
Patricia district — Peak loads, 1930 to 1933 --------- 59
Rural power districts — Mileage of primary lines approved - - - - - - 76
Aggregate peak loads, 1921 to 1933 ----------- 77
Abitibi Canyon power development — Diagram of works - ----- - 94
Rural power districts — Diagram illustrating growth of - - - - - --111
Electrical inspection department — Chart illustrating operations - - - - 126
Sandwich, Windsor and Amherstburg Railway — Operating statistics - - - - 129
guelph district railways — operating statistics - - - - - - - -' 131
Cost of electrical service in Municipalities served by The Hydro-Electric Power
Commission ----------- 407
MAP
Transmission lines and stations of The Hydro-Electric Power Commission of
Ontario -------------- At end of volume
TWENTY-SIXTH ANNUAL REPORT
OF THE
Hydro - Electric Power Commission
of Ontario
SECTION I
LEGAL
AT the 1933 Session of the Legislative Assembly of the Province of Ontario,
three Acts relating to the work of the Hydro-Electric Power Commission
of Ontario were passed. These are reproduced in full in Appendix I to this
report. The short titles to the said Acts are as follows:
The Power Commission Act, 1933, Chapter 47.
The Abitibi Canyon Power Development Act, 1933, Chapter 1.
The Manitoulin Rural Power District Act, 1933, Chapter 28.
The agreements between the Hydro-Electric Power Commission of Ontario
and the municipalities and corporations mentioned in the list hereunder given
were approved by Order-in-Council dated the 9th day of February, 1934.
Villages Townships
Colborne Dec. 12, 1932 Carrick * Nov. 14, 1932
Mildmay Nov. 30, 1932 Drummond Sept. 5, 1933
Oso Nov. 1, 1932
Sarawak Feb. 1, 1933
Verulam Mar. 6, 1933
Corporations
American Cyanamid Company Nov. 19, 1932
Falconbridge Nickel Mines Limited Feb. 9, 1933
Firestone Tire & Rubber Company of Canada Limited Nov. 1, 1932
His Majesty The King, in the right of the Province of Ontario (re'Mimico Asylum) . . . Aug. 1, 1932
His Majesty The King, in the right of the Province of Ontario (re Ontario Reforma-
tory) Aug. 1, 1932
Interlake Tissue Mills Co. Limited Sept. 11, 1933
[i]
1 — H.E
2 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
Corporations — Continued
The International Nickel Company of Canada Limited and The Huronian Company
Limited Dec. 23, 1932
National Trust Company Limited, Receiver and Manager of Great Lakes Paper
Company Lim ited June 14, 1933
Northern Empire Mines Company Limited May 27, 1933
Page-Hersey Tubes Limited Jan. 30, 1933
Provincial Paper Limited July 19, 1933
Provincial Paper Limited Sept. 1, 1933
Strathcona Paper Company Limited Jan. 1, 1933
Right-of-Way
Rural Power Lines
Wood-pole lines and extensions were constructed in the following rural
power districts during the year: Alexandria, Amherstburg, Aylmer, Ayr, Baden,
Bala, Barrie, Baysville, Beamsville, Beaumaris, Beaverton, Belleville, Bowrnan-
ville, Brant, Brockville, Bruce, Caledonia, Chatham, Chesterville, Clinton,
Cobourg, Colborne, Delaware, Drumbo, Dundas, Elmira, Essex, Fenelon Falls,
Fort William, Gait, Georgetown, Grantham, Guelph, Hawkestone, Huntsville.
Ingersoll, Iroquois, Kemptville, Keswick, Kingston, Kingsville, Lakefield,
Lindsay, London, Manitoulin, Markdale, Markham, Martintown, Maxville,
Millbrook, Napanee, Nepean, Newcastle, Newmarket, Norwood, Orangeville,
Oshawa, Owen Sound, Perth, Peterborough, Petrolia, Port Arthur, Prescott,
Preston, Renfrew, St. Marys, St. Thomas, Simcoe, Smiths Falls, Sparrow Lake,
Stirling, Strathroy, Streetsville, Tara, Thamesville, Trenton, Wallaceburg,
Walsingham, Waterdown, Waterford, Welland, Wellington, Williamsburg,
Woodbridge, Woodstock.
The practice, as in the past, has been to construct these lines on public
highways or roads where at all possible, but in a few cases, owing to local con-
ditions and the desire to avoid cutting trees, it has been found advisable to
place the lines on private property. In such cases the necessary right-of-way
has been acquired and compensation made for tree trimming or cutting.
There have also been a number of cases where, owing to road improvement
work being carried out by the Department of Public Highways or County Road
Commissions, it has been found necessary to change the location of existing pole
lines. In all such cases satisfactory arrangements have been made with the
department or commission having control of the roads in question.
High and Low Tension Wood-Pole Lines
Construction work has been carried out on the following high- and low-
tension wood-pole lines, and the necessary rights-of-way and tree trimming
rights have been secured during the year:
Trenton to Belleville. Port Hope to Newcastle.
Colborne to Cobourg. Bowmanville to Oshawa.
Auburn to Lakefield. Napanee to Bath.
Oshawa to Toronto. Delora to Marmora.
Norwood to Havelock. Smithville to Stoney Creek.
Warkworth to Newcombe. Burlington to National Fire Proofing Junc-
Newcombe to Welcome. tion.
Welcome to Oshawa. Kilsyth to Derby Mills.
934
HYDRO-ELECTRIC POWER COMMISSION
High and Low Tension Wood-Pole Lines — Continued
Walkerton to Mildmay.
Durham to Mount Forest. .
Meaford to Collingwood.
Kilsyth to Owen Sound.
Melancthon to Amaranth.
Fraxa to Orangeville.
Ragged Rapids to Bala.
Erbs Junction to Hanover.
Cornwall to Winchester.
Williamsburg to Winchester.
Lynn to Athens.
Winchester to Cardinal.
Dominionville to Alexandria.
Utterson to Huntsville.
Dominion Junction to Maxville.
Utterson to Windermere.
Muskoka Beach Junction to Muskoka Beach,
Windermere to Rosseau.
Dundas to Caledonia.
London to St. Thomas.
Guelph to Preston.
Kitchener to Stratford.
Kitchener to Waterloo.
Stratford to Sebringville.
Glengarry Junction to Glengarry Distributing
Station.
Woodstock to Dufferin.
Woodstock to Beachville.
St. Thomas to Kent.
St. Thomas to Sarnia.
Brant to Brantford.
Brant to Paris.
Paris to Ayr.
Ayr to Drumbo.
Cooksville to York Transformer Station.
Kent to Essex.
Winchester to Williamsburg.
St. Jacobs Distributing Station to Elmira.
Essex to Maidstone.
York Transformer Station to Weston.
York Transformer Station to New Toronto.
Wiltshire Avenue to Weston.
Kitchener Transformer Station to Erbs
Junction.
Welland to Port Colborne.
Erbs Junction to Stratford.
Fletcher to Tilbury.
Lythmore to DeCewsville.
Dundas to Binkley's Corners.
Ontario Gypsum Company to Hagersville.
York Mills to Newmarket.
Danforth Junction to West Hill.
Andrews Junction to Pottageville.
Langstaff to Mount Joy.
Dorchester Distributing Station to Dor-
chester.
Acton to Cheltenham.
Ontario Agricultural College (Guelph) to
Elora.
Harbour Hill to Goderich.
Sebringville to Milverton.
Milverton to Listowel.
Listowel to Palmerston.
Harriston Junction to Harriston.
Beachville to Embro.
Norwich to Otterville.
Mount Vernon to Burford.
Paris to Burford.
Brittania Junction to Streetsville.
Tilbury Junction to Fletcher.
Ridgetown to Rondeau.
Prince Albert to Ridgetown.
Como Junction to Dominion Sugar Company.
Prince Albert to Como.
Fletcher to Merlin.
Leamington Junction to Leamington Dis-
tributing Station.
Kleinburg Distributing Station to Bolton,
Arnprior to Galetta.
Burnstown to Arnprior.
Kirkfield Junction to Kirkfield Distributing
Station.
North Bay to Sturgeon Falls.
Smoky Falls to North Bay.
Substation Site
A site for a substation in connection with the Markham rural power district
was purchased during the year at Ringwood.
220,000-Volt Lines
The work of completing settlements for right-of-way, tree rights, damages,
etc. has been carried on during the year on the Gatineau high-tension lines,
and on the line between Chats Falls and Cumberland Junction, and between
Cumberland Junction and the Inter-provincial Boundary.
In a few cases where settlements could not be arrived at by negotiation, the
owners have called upon the official valuator to file his award. These awards
have been accepted by the owners in all cases, no appeals having been entered.
TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
General
During the year the operation of the Brantford and Hamilton Electric
Railway was discontinued, and as the right-of-way was no longer required,
efforts were made to dispose of it to the owners of the adjoining lands. In a
great majority of cases satisfactory arrangements have been made with such
owners to take over this right-of-way.
As the Commission was not successful in acquiring by negotiation the
lands owned by the Kingdon Mining, Smelting & Manufacturing Company in
the Township of Fitzroy, the matter was referred to the Ontario Municipal
Board for arbitration. These arbitration proceedings were quite prolonged,
involving sittings of the Board for forty-three days. The Board's award was
finally filed, and has been accepted by both parties, and the matter has been
closed.
In a number of cases surplus lands not required by the Commission in
connection with its works have been disposed of.
934 HYDRO-ELECTRIC POWER COMMISSION
SECTION II
OPERATION OF THE SYSTEMS
The past year's operation of the systems has been satisfactory. Few
interruptions to service occurred, and failures of equipment were relatively
few and not serious in extent. On June 7, 1933, a storm of extreme severity,
accompanied by high winds, lightning and rain, caused damage in many districts
between London, Toronto and Niagara Falls. Twelve steel towers collapsed
during the storm, and damage was done to various low-tension lines, and to
some of the station equipment connected to them, the total cost of repairs
approximating $27,000. With this exception there were no failures of lines or
apparatus which resulted in extensive disturbances to service. In another part
of this section details will be found regarding such failures of equipment as
occurred in the ordinary course of operation, together with an outline of the
repairs made and the maintenance work carried out.
The Eastern Ontario and Georgian Bay systems suffered from a lack of
rainfall which reduced the stream flow and the capacity of the generating plants.
On the Georgian Bay system the reduction in generating capacity was offset
by an increased transfer of power from the Niagara system. On the Eastern
Ontario system the low stream flow during certain periods reduced the capacity
of all the generating stations on the Trent river to less than 40 per cent of their
normal maximum capacity, and a severe power shortage would have been
experienced if a supplementary reserve supply of power had not been available
from the Gatineau Power Co. The Nipissing district ^so experienced a period
of low precipitation, but the storage works constructed by the Commission
made it possible for the stream flow to be maintained in volume adequate to
enable the generating plants to supply the demand for power.
It has been customary in this section of the Report to give a summary of
load conditions. A load graph is given in connection with each system, showing
the load month by month throughout the year, and extending back over a
period of time depending on the age of the system and the records available.
These graphs may be consulted for details regarding the load on each system,
the following remarks dealing mainly with the total load of the Commission,
that is, the combined load of the systems.
In an enterprise as large as that of the Commission increases are apt to
occur at one point while decreases occur at another point. Under such conditions
broad generalizations cannot be expected to hold true in all cases, and to avoid
6 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
any possibility of misunderstanding or appearance of inaccuracy, attention is
called to the importance of treating the statements given herein as applying
only to the combined total of the systems' load, or to that section of the load
specifically referred to in the text.
In the fiscal year ending October 31, 1933, the total load of the Commission,
for all systems combined, amounted to 4,612.000,000 kw-hrs., exceeding that of
1932 by 171,000,000 kw-hrs., as shown in the table of power generated and
purchased given on the next page.
Of more importance than this increase in the average load for the year,
is the upward trend of load which became apparent during the latter half of
the year. In last year's Annual Report reference was made to the reduction in
load which had occurred during the depression. In that Report it was pointed
out how the downward trend appeared in 1930 and continued throughout 1931,
but in 1932 the rate of decrease was checked, the reduction for 1932 being only
1.2 per cent as against a decline of 15 per cent during 1931. During the months
of December, 1932, and January, 1933, there was a marked slump in the total
load, to which a downward trend in the primary load and a loss of secondary
load both contributed. In February a substantial block of secondary power
was added, which very largely compensated for the decreases in both primary
and secondary power during the previous months. In July a very substantial
increase was made in both primary and secondary load, and further increases
occurred during the succeeding months.
During the last four months of the fiscal year 1933, the total load exceeded
that of the corresponding months of the previous year by about 245,000,000
kilowatt-hours. In consequence, the decreases during the earlier part of the
year were more than off-set by the increases during the latter part of the year,
and the complete year shows a net increase of 171,000,000 kilowatt-hours.
In October, 1933, the total peak load of the Commission reached the high
figure of 1,366,000 horsepower, an increase of 23 per cent over the corresponding
month of the previous year. This is the highest load ever carried by the Com-
mission, in any month, either before or since the beginning of the depression.
The above figures should not be used as an indication of business conditions
in the Province, or for the purpose of forecasting load during the coming year,
without proper allowance for the quantity of secondary power included therein.
"Secondary" power is a term applied to power which is sold subject to
unlimited interruptions, to reduction or to complete withdrawal, at any time
it is required for use by municipalities, or for the maintenance of the supply
of firm power. During 1933, the Commission was able to effect the sale of large
blocks of power on this basis, mainly for the generation of steam by electricity.
Under these arrangements energy from Canadian water powers is utilized and
replaces large quantities of imported coal. In connection with such use, it
has not been necessary for the Commission to supply any additional generating
equipment, and the power is still effective as a system reserve for "firm power"
customers, and is available to meet their demands at any time.
Recent developments in the sale of secondary power have made it necessary
this year to present in a somewhat different manner the figures relating to
certain power which has been sold for the purpose of steam generation. Prior
1934 HYDRO-ELECTRIC POWER COMMISSION 7
to 1930 the rapid growth of the Commission's loads had prevented the provision
of a suitable amount of reserve capacity, and consequently the amount of
secondary or off-peak power sold was relatively small. From October, 1930,
to October, 1932, inclusive, a block of power was "resold" to the Gatineau
Power Company to be used for steam generation. This transaction was reflected,
in the statistics presented, in a reduction of the power purchased from the
Gatineau Power Company, because it was the equivalent of a temporary and
revocable reduction in capacity, and as at that time no secondary power was
distributed in Ontario, it did not seem appropriate to include the contract
power thus temporarily relinquished, as an addition to the system load figures.
During 1933, in which year the sale of substantial quantities of secondary power
began in Ontario, the resale to the Gatineau Power Company also recommenced.
Since it is necessary to include Ontario's new load of secondary power in the
figures for total load, and since the resale to the Gatineau Power Company
represents secondary power which is similar both in the characteristics of being
subject to immediate and unlimited interruptions and in the use to which it is
put, it appears to be appropriate and necessary now to include this "resale"
power in the figures for total load. In making comparisons, therefore, of certain
loads for 1933 and for 1932 it has been necessary to show them both on the
same basis and, in some cases, this has required revision in the 1932 figures to
which attention has, herein, been directed.
In general it is only industries consuming relatively large quantities of
power which can utilize secondary power. During the past year the Commission
has been in a position to offer sufficiently large blocks of power to make the
use of this class of power attractive to certain industries, and since February,
1933, the secondary load in Ontario, which was previously of negligible pro-
portions, has been built up to an extent which materially affects the statistics
for the total load. While it is hoped that this class of load will always be continued
as a source of revenue from reserve generating capacity, it is subject to wide and
irregular fluctuations according to load and business conditions, and should not
be included in any study of the firm load trend, nor should it be included in
any statistics of electric power consumption which are intended for use as an
index of business conditions generally. The firm load is of a different nature
and is generally regarded as an excellent business index, due to the fact that
such power is used by so many of the factories, stores and residences throughout
the districts served. It is not subject to the irregular fluctuations of secondary
power.
For the above reasons it is of interest to compare the Commission's firm
load in Ontario during 1933 with that of the previous year, omitting all secondary
and export power.
In September and October, 1932, the firm load showed the usual seasonal
increases. This continued during the month of November, 1932 (which forms
the first month of the past fiscal year 1932-33). However, in December, 1932,
the firm load showed a definite downward trend which continued until May,
1933. This downward trend was more marked than the usual seasonal decline
of load, which normally begins in February and continues until some time in
August.
In May, 1933, the downward trend terminated, and an upward movement
commenced, which was of an even more marked character than the downward
trend of the previous months. This upward trend continued consistently from
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
TOTAL POWER GENERATED AND
HYDRO-ELECTRIC GENERATING PLANTS
Generating plants
Maximum
normal
plant
capacity
Oct. 31,
1933,
horsepower
Peak load
during
fiscal year
1932-1933
horsepower
Total output
during
fiscal vear
1932-1933
kilowatt-hours
Niagara system
Queenston-Chippawa — Niagara river. . . .
500,000
180,000
150,000
96,000
50,000
24,000
5,600
1,600
2,300
600
5,800
1,200
7,800
400
500
300
4,500
3,500
7,000
4,500
10,500
4,200
15,300
2,400
1,000
3,000
400
5,400
1,100
73,500
50,000
2,100
1,200
1,700
5,900
2,900
7,500
4,000
55,000
461,126
119,303
70,375
94,504
42,091
6,011
1,609
2,145
583
5,791
1,227
7,614
382
503
3,619
1,810
7,507
4,625
10,456
3,150
15,282
1,984
938
3,117
375
1,588
402
48,700
48,200
2,366
1,307
1,910
5,563
2,882
6,233
2,627
45,389
1,834,328,000
"Ontario Power" — Niagara river
145,624,000
"Toronto Power" — Niagara river
64,521,000
Chats Falls — Ottawa River (Commission's
half)
124,024,550
Dominion Power and Trans, system*
Decew Falls — Welland Canal
97,082,300
Steam Plant — Hamilton
24,800
Georgian Bay system
South Falls — South Muskoka river
20,495,760
Hanna Chute — South Muskoka river
Trethewey Falls — South Muskoka river
Bala No. 1 and 2 — Muskoka river
6,676,800
8,925,600
2,224,344
Big Chute — Severn river
16,396,920
Wasdells Falls — Severn river
3,403,240
Eugenia Falls — Beaver river
17,794,960
Hanover — Saugeen river
104,524
Walkerton — Saugeen river
1,307,100
Southampton — Saugeen river. ...
Eastern Ontario system
Sidney-Dam No. 2 — Trent river
7,826,700
Frankford-Dam No. 5 — Trent river
225,500
Meyersburg-Dam No. 8 — Trent river
11,160,530
Hague's Reach-Dam No. 9 — Trent river
Ranney Falls-Dam No. 10 — Trent river
7,245,700
13,937,820
Seymour-Dam No. 11 — Trent river
7,981,130
Heely Falls-Dam No. 14 — Trent river
20,118,400
Auburn-Dam No. 18 — Otonabee river
6,467,050
Fenelon Falls- Dam No. 30-Sturgeon river
1,410,300
High Falls — Mississippi river ...
4,263,720
Carleton Place — Mississippi river
11,848
Calabogie — Madawaska river ...
4,433,951
Galetta — Mississippi river
12,660
Thunder Bay system
Cameron Falls — Nipigon river. ...
115,494,000
Alexander — Nipigon river
173,030,400
Northern Ontario properties
Nipissing district
Nipissing — South river
4,728,040
Bingham Chute — South river
3,040,800
Elliott Chute — South river
3,989,000
Sudbury district
Coniston — Wanapitei river
16,322,328
McVittie — Wanapitei river. ...
12,076,344
Stinson — Wanapitei river
17,335,704
Patricia district
Ear Falls — English river
10,679,000
Abitibi district
Abitibi Canvon — Abitibi river
30,950,000
Total generated
1,292,700
t
2,815,674,823
*In process of incorporation with the Niagara system.
fBecause the peak loads on the various generating plants and purchased power sources
usually occur at different times, the sum of the individual peak loads would not represent the
sum of the peak loads on the systems. These in the case of each system must relate to the
maximum load occurring at any one time. Consequently, the column headed "Peak Load" is
not totalled.
1934
HYDRO-ELECTRIC POWER COMMISSION
PURCHASED— ALL SYSTEMS
POWER PURCHASED
Power source
Contract
amount
horsepower
Oct. 31, 1933
Total
purchased
kilowatt-hours
Canadian Niagara Power Co. — 25 cycle
Gatineau Power Co. — 25 cycle
Ottawa Valley Power Co
Beauharnois Light, Heat and Power Co. .
McLaren Quebec Power Co
Canadian Niagara Power Co. — For D.P. & T. 66-cycle system
Campbellford Water & Light Commission §
Cedars Rapids Power Co
M. F. Beach Estate
Rideau Power Co
Ottawa & Hull Power & Mfg. Co
Gatineau Power Co. — 60 cycle
Orillia Water, Light & Power Commission §
Manitoulin Pulp Co
Ontario Power Service Corporation
Total purchased
20,000
260,000
96,000
75,000
20,000
10,000
' 7,500
500
487
20,000
36,000
"l50
95,132,300
,074,498,785 1
124,024,550
157,340,000
28,835,800
57,855,000
'29,779,500
831,600
2,822,800
63,660,600
128,241,500
—734,530
99,200
34,054,060
1, 796,441, 165t
Power purchased, contract amount, 1933
Maximum normal plant capacity, 1933 . .
545,637 horsepower
1,292,700
Total available capacity generated and purchased, 1933 1,838,337
Total available capacity generated and purchased, 1932 1,760,052
Difference .(increase) 78,285
Total energy purchased, 1933 1,796,441,165 kilowatt-hours|
Total energy generated, 1933 2,815,674,823 kilowatt hours
Total energy generated and purchased, 1933 4,612,115,988 kilowatt hours!
Total energy generated and purchased, 1932 4,440,447,470 kilowatt hours}:
Difference (increase) 171,668,518 kilowatt hours
Jlncludes secondary power resold to the Gatineau Power Company.
§Reciprocal arrangement for surplus power.
CAUTION: The figures for "Maximum Normal Plant Capacity" reflect the capacity of the
various plants under the most favourable operating conditions which can reasonably be considered
as normal, taking into consideration turbine capacity as well as generator capacity and also the
net operating head and available water supply.
Owing, among other things, to changes in generating equipment due to wear and tear or
the replacement of parts, also to changes in the limitations governing water levels and effective
net heads, the maximum normal plant capacity is not a fixed quantity but is one which must be
revised from time to time. It will be noted that several revisions have been made in the ratings
shown this year, the capacity of some plants being rated lower and others higher.
It will be noted that the capacity of the Queenston plant appeared in last year's Report as
522,000 horsepower and is herein reduced to 500,000 horsepower. The reduction in peak capacity
is a consequence of operating the plant at a high daily load factor in order to obtain a maximum
of energy from the water allowable under the Boundary Waters Treaty. At lower daily load
factors the maximum peak capacity is substantially higher.
It is particularly important to bear in mind that the column headed "Maximum Normal
Plant Capacity" cannot be taken as an indication of the dependable capacity of the various plants;
in some cases it is, but in many cases it is not. As an illustration it may be noted that while
under favourable circumstances the plants of the Eastern Ontario System, taken collectively,
might supply a peak demand equal to or even in excess of the sum of their maximum normal
ratings, the maximum output which could be obtained from them during part of the month
of October, 1933, was only about 40 per cent of this rating.
Chief among the factors which govern the maximum dependable capacity of a hydraulic
power plant and which are not reflected in column headed "Maximum Normal Plant Capacity"
are abnormal variations in water supply and operating limitations encountered when plants
are so situated on a given stream as to be affected bv one another.
10 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
month to month. By June practically all lost ground had been regained, and
in October the firm load was higher than in the corresponding months of 1932
or 1931, although still slightly below 1930 which was the record year for all
time. This steady upward trend of the firm load in Ontario during the latter
half of 1933 was one of the most encouraging features of the load situation.
During the months of November and December the normal seasonal increases
in firm load occurred; thus the gains made during the latter part of the fiscal
year were retained.
While the above comments refer to the Commission's load on all systems
combined, somewhat similar remarks might be made for each system, although
there are special variations. In the following sub-sections each system is reported
individually, and load graphs are given showing the load month by month.
The graphs for the Niagara, Eastern Ontario, and Thunder Bay systems,
and for the Sudbury, Abitibi and Patricia districts, all show the encouraging
upward trend during the latter part of the year. The Georgian Bay system
and the Nipissing district do not share in this gain, but the load continued
around the same levels as during the previous year. It will be noted that these
latter systems did not suffer the marked decline of other systems in the earlier
years of the depression. While not yet showing any upward trend, they were
later in showing any downward trend, and have little ground to regain.
Forestry
The Forestry division's diagnosis of trees on Ontario highways along which
the Commission's power and telephone lines extend continues to reveal hitherto
unknown hazards to life, property and service. The reproduction of two photo-
graphs given herein illustrates only one of the numerous cases which are being
found on road allowances and on private property adjacent to the Commission's
lines and to the travelled highways. The Department of Highways, county,
township and municipal authorities, as well as all property owners, are advised
of the condition of such trees as these and arrangements made to remove the
menace.
Forestry squads have been continuously employed on the Niagara system
throughout the year, operations being carried on in practically all districts,
over 1,114 miles of transmission and high-tension telephone lines. Georgian Bay
system operations were carried on over a period of six months, and embraced
128 miles of transmission lines in Eugenia, Severn and Wasdells districts.
Eastern Ontario system operations involved 31 miles of transmission line in the
St. Lawrence and Central Ontario districts. Some work was done to provide
adequate clearance for reconstruction required by the Transmission and
Distribution sections of the Engineering department.
The work involved in all forestry line-clearance operations, over approxi-
mately 1,300 miles of Commission-owned power and telephone lines on all
systems, cost $87,385, including labour, tree wound dressing, cabling and other
materials as well as travelling expenses and similar Forestry division overhead.
934
HYDRO-ELECTRIC POWER COMMISSION
II
A MENACE TO LIFE, PROPERTY AND SERVICE
White pine tree standing alongside the Commission's transmission line on the
King's Highway No. 11
LEFT: View of base cavity through which fungus entered, destroying the sap and heartwood
far up into the trunk
RIGHT: View of highway, low-tension line and tree
OPERATING DEPARTMENT— FORESTRY DIVISION
The work and costs may be classified as below:
Quantity
Total
cost
Average
cost
Underbrushing
2,239 pole spans
(or 63 miles)
12,878 trees
36,046 trees
$3,732
29,104
54,549
$1 66
Tree removals
2 26
Line clearance, shaping and corrective pruning. .
1.51
Total
48,924 trees
$87,385
It will be noted that this year the costs of underbrushing and tree removal
have been segregated, whereas in previous years these items were included in
the total costs and the average cost per tree. The overall cost per tree this year
shows a slight reduction.
\2 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
The following is a brief explanation of the work involved in line clearance,
shaping and corrective pruning:
(a) The cutting of twigs and branches back to laterals, and the removal
of all dead wood, to clear lines;
(b) Corrective trimming by removal of all unsightly diseased stubs, to
improve the health and appearance of the tree;
(c) Cabling of structurally weak or splitting crotched trees, and of heavy
overhanging limbs that could not be removed without impairing the
symmetry of the tree, for the protection of the Commission's lines and
of the travelling public.
(d) Shaping tree by trimming branches beyond area required for line
clearance, to preserve symmetry of the tree.
It is estimated that the extensive corrective trimming, shaping, cabling,
and removal of dead wood required for the first operation on each line costs at
least fifty per cent more than pruning for line clearance only. On this basis
the cost of pruning for line clearance alone would amount to about $1.00 per tree.
Before undertaking pruning operations or tree removals on highways,
forestry foremen interview both the adjacent property owners and the municipal
authorities. While this procedure is necessary to secure co-operation and
harmony, it will be appreciated that it adds to the cost of the operations, and
such cost is included in the above figures.
The Forestry division has given the Operating department district patrolmen
some practical training in the scientific methods of pruning trees for line clearance
so that they might become qualified to do this work when required. During
the past year twenty different patrolmen have reported for training while
forestry operations were in progress in their respective districts. Six completed
training and were approved. The others were either called for important line
work or forestry operations were suspended in the district before training was
completed. They will continue training when forestry operations are re-opened
in the district.
During the past year, four municipal Hydro systems have availed themselves
of the opportunity to employ the Commission's Forestry Division service. They
report that their commissions and the local property owners are highly pleased
with the quality of work done and with the efficiency of the foresters in carrying
on this hazardous class of work without requiring or causing service inter-
ruptions. This work involved only line clearance pruning, and the removal of
all dead wood, to clear low-voltage lines. No corrective pruning, extensive
shaping, or cabling, and only a small percentage of tree removals were required.
The trees diagnosed as diseased and dangerous were to be removed by the
unemployed. This type of pruning for local distribution lines is vastly different
from the clearance required on 10, 000- volt to 60, 000- volt power transmission
lines. The four municipal operations combined involved pruning 812 trees at
a total cost of $722, an average cost of 89 cents per tree.
934
HYDRO-ELECTRIC POWER COMMISSION
13
OPERATING DEPARTMENT-FORESTRY DIVISION
CROWN AND SIDE PRUNING
Tree pruned for line clearance and appearance. Only
crown and side pruning was required for line clear-
ance, but to avoid destroying the symmetry of this
tree, the lower branches were trimmed on the line
and opposite side of tree, increasing the cost but
preserving appearance
A complete survey of all trees within the corporate limits has been made
for several other municipal Hydro systems who later* contemplate the use of
this service. One of these surveys revealed the fact that of a total of 1,303 trees
inspected, 101 were diseased and dangerous to life and property. Through co-
operation with the municipal authorities, these latter trees are being removed
by the unemployed as a relief measure.
In co-operation with the Ontario Forestry Branch, the Queenston-Chippawa
Canal reforestation project was undertaken two years ago to establish a tree-
lined area on both banks of the canal. This was done primarily to eliminate
drifting snow and ice, as well as other debris, getting in to the canal, and to
protect the steep banks from erosion. A rather high mortality among the trees
resulted from the drouth of the last two seasons. It was, therefore, necessary
to replace approximately 20,000 trees. The areas immediately surrounding the
seven bridges are being developed by informal group planting. Approximately
7,500 conifers of the following species were planted this year: — white cedar,
14 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
Austrian pine, larch, Scotch pine, white spruce, Jack and Muhgo pine. The
total cost of this year's reforestation and informal development of bridge
approaches amounted to $727.
Many letters have been received commending the Commission upon the
success of its efforts to protect trees along the highways, and to preserve their
beauty as well as the scenic effect. This is especially gratifying in view of the
difficulty of preserving the beauty of the trees without sacrificing the clearance
necessary for satisfactory transmission line operation.
An expression of gratitude is due the Department of Highways, county,
township and municipal officials, as well as various property owners, for their
kind co-operation which has made it possible for this work to be carried on
harmoniously in all parts of the Province.
Radio Communication
The commission's short-wave stations at Toronto, Cameron falls and Ear
falls have continued in service all year with no important changes in equipment.
There has not been as much interference from atmospheric and other causes
as was experienced in 1932, and communication between Toronto and the
stations mentioned has been maintained on a regular schedule.
NIAGARA SYSTEM
Queenston Station
Generating Stations
Systematic inspection and maintenance of all apparatus and parts were
carried out in accordance with the regular schedules, and in this connection
generator and turbine units were removed from service as noted below.
Number 1 generator and turbine unit were out of service from June 5 to
June 23. During this period the governor was dismantled, worn parts were
replaced and reassembled, the runner and seal ring were inspected, and the
lignum vitae bearing was reblocked. The generator stator was cleaned and
varnished and field coils were tested. The Johnson valve was cleaned and the
valve seats were machined.
Number 2 unit was out of service from June 26 to July 13. During this
period the governor was dismantled, worn parts were replaced and reassembled.
The lignum vitae bearing was reblocked and the runner, draft tubes and seal
rings were inspected. The generator stator was cleaned and varnished, and the
Johnson valve controls were cleaned and repaired
Number 3 unit was out of service from September 1 to September 14,
during which period repairs were made to the governor controls, the turbine
bearing was reblocked, and the racks, draft tube, runner and seal rings were
inspected. The generator windings were cleaned, tested and varnished.
1934 HYDRO-ELECTRIC POWER COMMISSION 15
Number 4 unit was out of service from September 18 to October 3. During
this period the Johnson valve was overhauled, the lignum vitae bearing was
reblocked and the draft tube, runner and seals were inspected. The governor
was dismantled and reassembled, worn parts being replaced.
Number 5 unit was out of service from May 15 to June 3. During this
period the governor was dismantled and reassembled, worn parts being replaced,
the lignum vitae bearing was reblocked, the Johnson valve controls were cleaned
and repaired, and the draft tube was drained and inspected. The generator
stator and field coils were inspected and cleaned.
Number 6 unit was out of service from October 10 to October 24. During
this period the Johnson valve was overhauled and the draft tube, runner and
seals were inspected. Minor repairs were made to the exciter armature.
Number 7 unit was out of service from July 14 to July 29, the entire unit
being dismantled. During this period a large amount of welding was carried
out on the runner and seal ring. It was found necessary to replace the turbine
bronze sleeve section on the shaft. The governor was dismantled and reassembled,
worn parts being replaced. The lignum vitae bearing was reblocked. The
generator stator and field windings were cleaned and varnished.
During the above outages of the different units, the low-tension and high-
tension breakers were inspected and the oil changed. The transformers were
opened for inspection of all internal connections.
During the year the governors on units numbers 6, 7 and 9 were equipped
with load limiting devices, and this work is being continued until all governors
are so equipped.
Experiments have been made with the use of stainless steel welding rod for
the final surface coat on turbine runners during the past few years, and it has
been found that this metal has several times the life of that previously used.
A new 32-volt control battery was purchased and installed during the
latter part of the year, replacing two units previously in service.
Several hundred trees and shrubs were planted on the gorge banks and
grounds adjacent to the power house and screen house with a view to beautifying
the grounds and protecting the gorge banks.
Ontario Power Station
The service rendered by the Ontario Power generating station was extremely
good during the year, there being no failures of major equipment and no diffi-
culties encountered in its operation. All equipment was regularly inspected
and repairs and adjustments were made where necessary to maintain the plant
in efficient condition. All equipment being in good condition, no extensive
maintenance work was required during the year.
16
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
HORSEPOW
1.000.000
900.000
800.000
700.000
600.000
500.000
400.000
300.000
200.000
100.000
iBiii!isSssa»i!i!i3l8fialniii!isSss8hEifi!i3S^8iuiiiIisSss8.
1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 j 1 1 1 1 1 1 1 1
NIAGARA SYSTEM ~T
PEAK LOADS IN ONTARIO /
HYDRO-ELECTRIC POWER COMMISSION /
OF ONTARIO
I i qoo I , /
1 i JO O 1 -j
i i you III /i j r
\ a. io^? / \ iA I /
\ \ J \ 1 VI / / \ /
V*i I J \ U / / \ A /
\ 1 \ 1 \ / / \ /
1 \ III t-' / \/
/ \ ^ P
1/ W ^ 1 \ n-oi !
V i / til] V i
I 1 1 t I J 7 i__„T3n___t f .
± \ ' ] x<& L r l
\ / i y^ / w 1
« M / i 1 1 1 11/ u
/ \ 1 Q9fi V, . J V
/ \ I II Mi > lll/l
1QOC / 1 ! X [ i / ^tv /
9 5 / iNJ / 1 \7 e^
ir t t t i:\t-t-
\ J ' n h J. ' 4 . 4 ,___._! /__
^\/ " f .\ui c: J he an nipt toad increase which occurred \ J
of the Ontario load of the Toronto Power Co. and of \ /
the Ontario Power Co. In November, 1931, the load of \/
the Dominion Power e" 7 ransmisswn Co. was included ~[ t
of these properties into the Niagara System.
1 MINI/
1Q?^J
/
1Q9? ►/ V A/ - "^ i I
— — — . . \7D L.C. j 'Xl/ V
1 Q O 1 / ^ '
i y l. i / \ /
1QOA Mill / N *'"> A /
1920 U ^
^ y\ / ^"^ 1 q 1 fi ' Li
^s mi7 I I , ■"T
1 ■ • ■ — I J 1 / r~
■p 1915' ^^ , U-H1 j .
-^ X 101^ >-»**
1Q1 3 ■ T
: — - ■ ■ ■ , i i y 1 *- /
1 Q 1 t i I • I I II I ,- •* ""^ *■ - - - "" "" ~ _ j_
lHlIIil«SlsiHilSiiS§lsllSllliilSysll3slIi?i8§IM5lIli?i5sla
HORSEPOWER
.000.000
900.000
800.000
700.000
600.000
500.000
400.000
300.000
200,000
100.000
1934
HYDRO-ELECTRIC POWER COMMISSION
17
HORSEPOWER
FEB
MAH
APR
JUNE
Jill Y
MM)
SEPT
OCT
NOV
PEC
JAN
FEB
MAR
APR
JUNt
JULY
AUG
SEPT
OCT
NOV
OEC
JAN
FEB
MAR
APR
MAY
JUNE
JULY
AUC,
SEPT
OCT
NOV
OEC
JAN
FFB
MAR
APR
MAY
JUNF
JULY
AUG
SEPT
OCT
NOV
DEC
JAN
FEB
MAR
APR
JUNE
JULY
AUG
SEPT
NOV
r"
Total System Load — ^/
_,
Primary Load and Obligations |
i
..._ /A /_____,_
__!_ t—\-t-—r^/-——U
H ^t-v n P r
1.000,000 t- ■ ■ f-- ■ Li -J- --■■[-, -i _ -
1 i- \ r- , i I J /
±_ 1 ___ ____ h ]__J 1 S L_
_■& i* rt ik __,_____]__ . n __
__fc_ r __J_____5 f[V_V_ U\ I
«.«-__}- V-l- - 'I -W.—UXX-—^-'-
" M "___^Li_ lL_„, j „ l_-a— -Ll— _Jh-
ii_ a jl__\____n_ -A— $
_ Jj__. -_l_ _H__ I_ Jj y L» H
F2 L__ ____ t— -J- - M i -
t *^ / t. f 1 1 r
800.0M f-r-j \- h Mj
:::/ _:: *
1 f u
______
r
.IQQn IQOI 10*59 1QOO
iyou iy«_>i iy«_>__. lyoo
JAN
HB
MAR
MAY
JUNE
AIK,
',EPT
OCT
NOV
DEC
FEB
MAR
APR
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
FEB
APR
MAY
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
JAN
FFB
MAR
APR
JUNE
\LPT
OCT
NOV
DEC
JAN
FEB
MAR
APR
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
HORSEPOWER
1,200.000
1,100,000
1,000.000
900,000
800,000
700,000
600,000
SUPPLEMENTARY DIAGRAM— NIAGARA SYSTEM PEAK LOADS
Notes
TOTAL SYSTEM LOAD includes power exported to Quebec and the United States
as well as the Ontario load shown on the opposite page
PRIMARY LOAD AND OBLIGATIONS as the term implies, includes both the
primary load and the contractual obligations for primary power to Ontario
Companies supplied directly by the Commission in excess of power actually taken
by them
The scaling of the cliff, and the construction of a dry wall to protect the
buildings from falling rock, which was reported under way in the last Annual
Report, was completed during the latter part of 1932. Repairs were made to
the outer concrete walls of the power house.
All machine shop equipment is being moved to a permanent location in
the north end of the main generating station, in a space formerly occupied by
a 16-foot boring mill which has been moved to Queenston. The relocation of
this equipment will permit the removal of temporary buildings at the north
end of the power house which were originally erected for construction purposes.
18 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
Toronto Power Station
No difficulties were encountered in the operation of this plant during the
year, although two generators failed in service during a lightning storm on
July 19, and required minor repairs. Systematic inspection and maintenance
of all apparatus was carried out in accordance with the regular schedules; the
larger maintenance items are as noted below.
On number 1 unit the upper turbine rods were packed and the lower turbine
bearing was changed.
The generator on number 3 unit failed in service on July 19 during a lightning
storm and it was found necessary to replace three coils in the armature. The
stator was given a thorough cleaning, and all coils were varnished.
On number 4 unit the field was removed and the stator coils cleaned and
varnished. During this period the oil and water service pipes to both generator
bearings were re-arranged. The governor was dismantled, worn parts were
replaced and the governor was reassembled. The turbine and guide bearings
were also refitted.
On number 5 unit the upper turbine bearing was changed and the lower
turbine bearing was inspected. The guide bearings on decks number 3, 4 and 5
were inspected and the oil grooves recut. Steel gear guards were installed under
the governor, and the wheel-gates were adjusted to provide for tighter closing.
On number 6 unit the field was removed and the generator coils were cleaned
and varnished. The guide bearings on decks number 2. 3 and 4 were inspected
and oil grooves recut, and the guide bearing on deck number 5 was replaced.
The top and bottom generator bearings were changed, and steel gear guards
were placed under the governor.
The armature of number 7 unit failed in service on July 19 during a lightning
storm, and it was necessary to remove the field and replace five coils in the
armature. The stator was thoroughly cleaned and the coils re varnished. The
top generator bearing and the guide bearings on deck number 5 were changed.
During the severe wind and lightning storm on June 7 a 6,000 kv-a. trans-
former at the Toronto Power transformer station failed in service. This unit
has not yet been repaired.
The usual painting and general maintenance work was carried out in
accordance with the regular schedules.
Ghats Falls Station — Ottawa River
The year 1932-3 was the first complete year's operation with eight units
in service. The performance of all equipment was highly satisfactory, requiring
no major maintenance or repair work. All inspection and routine maintenance
work has been carried out in accordance with a regular schedule. A complete
check of all relay and metering equipment was made.
1934
HYDRO-ELECTRIC POWER COMMISSION
KILOWATT-HOURS
400.000.000
SEPT
OCT
NOV
DEC
JAN
FEB
APR
JUNE
AUC
S£PT
OCT
NOV
OEC
FEB
MAR
APR
JULY
SEPT
OCT
NOV
DEC
JAN
FEB
MAR
APR
MAY
JUNE
JULY
AUG
S£PT
OCT
NOV
DEC
JAN
FEB
MAR
APR
MAY
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
[ 1 M 1 II 1 II i 1 1 II 1 I II II 1 1 It 1 1 1 1 1 ]
NIAGARA SYSTEM
. TOTAL KILOWATT-HOUR LOAD _
IN ONTARIO
HYDROELECTRIC POWER COMMISSION
-
! 1 1 1 1 1 -
1 oon
Mill
1QOO
i y ju
ii?oo
300.000.000
u
"" - i~ J"
-1 Q *3 9 - """■*_
-
I lyo^ - _
1 QQ1 - "
I yo i _ _ __
_
~ " _ — = ~ ~ lyZy :
- *
- n . ~ - 1 "
- "" - _"- -
-__ -_
- - 1QOQ -
200.000.000
__ - - _ 13/P
-
1 _ _- m
- 1 Q07 -
-
- i, y L. /
\c\oc. Ill I I r , - —
_ _--
1 "f-O III
- IQ*?^
NOTE: The abrupt load tnrrease which occurred
i yzD
of the Ontario load of the Toronto Power Co. and of 1Q?A
the Ontario Power Co. In November, 1931, the load of
the Dominion Power & Transmission Co. was included
of these properties into the Niagara System.
U
100.000,000
I . ±:.=4=:
~ - - 1 QOQ -
iy^o
- -
-_- n
.1QOO . -~
-lyzu
- ■ ■ \zf/L\ n
1Q1Q
iy i y
m
IAN
IEB
APR
MAI
JUNE
SEPT
NOV
JAN
FtB
APR
JUNE
AUG
SEPT
OCT
DEC
FEB
MAR
JUNE
JULY
bEPT
OCT
NOV
DEC
EEB
APR
JUNE
AUG
OCT
DEC
JAN
EEB
APR
JUNE
JULT
AUG
OCT
DEL
KILOWATT-HOURS
400.000.000
300.000,000
200.000,000
100.000.000
The Ottawa river flow reached a maximum of 150,000 c.f.s. during the
spring flood and receded to a minimum of 12,000 c.f.s. in October, the extremely
low flow resulting from the small precipitation during the summer. Throughout
this wide variation of flow no difficulty was experienced in maintaining the water
levels within the prescribed limits.
The responsibility for maintaining system frequency and time service was
transferred to this station from the Niagara Falls plants during the year. For
this purpose a type "B" Telechron clock was installed in the control room,
which, in conjunction with a graphic time-error meter installed at the load
20 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
supervisor's office at Niagara Falls, enables the operators to maintain time
service to the districts supplied from Toronto, York, Cooksville and Hamilton
transformer stations within the limits of plus or minus five seconds from standard
time. Similar time service is given to other parts of the Niagara high-tension
system through frequency control at Niagara Falls.
For the purpose of placing cars, moving heavy material and handling tail-
race stop-logs, a large Browning crane was purchased.
During the early part of the past fiscal year the remaining construction
details were completed. A complete inventory has been made of all construction
material, stores, spare parts, etc., remaining on hand after the completion of
construction, and this material is now being offered for sale.
Decew Falls Generating Station
This plant was in continuous operation throughout the year; no difficulties
were encountered in its operation, and no failures of equipment occurred. No
extensive maintenance work was carried out during the year, but regular
inspection and repairs were made in accordance with the established schedule,
and the plant was kept in satisfactory operating condition.
The water-wheel governors of number 5 and number 7 units were rebuilt
and a new main control valve was built for number 1 water-wheel. The exterior
trim of the generating station building and transformer house was painted.
Dominion Power Steam Station — Hamilton
The 60-cycle steam plant at Hamilton was operated during the year as a
standby for electric service and for the generation of steam for commercial
purposes. While it was not necessary to operate the steam turbo-generator for
power purposes during the year, this unit was operated from time to time as
a synchronous condenser for voltage regulation on the system. Experiments
were carried out in the burning of coke breeze, along with the regular slack
coal. These were successful and fuel costs at this station have been reduced.
Transmission
The 220,000-volt lines between Toronto and the Ottawa river (Chats Falls),
and from this point to the Ontario-Quebec boundary line connecting with the
Beauharnois development, gave very satisfactory service and no difficulties were
encountered in the operation or maintenance of these lines.
There were two total interruptions of all three circuits, caused by lightning,
resulting in disturbances to service in the Toronto area. There were fourteen
single-circuit outages on this system caused by lightning; these latter outages,
however, did not affect service. None of the above disturbances caused damage
to lines or equipment, and the immediate return of the equipment to service
was possible.
1934 HYDRO-ELECTRIC POWER COMMISSION 21
On July 1, the 220, 000- volt circuit from the Masson station of the MacLaren-
Quebec Power Company was connected to the Beauharnois-Chats Falls line and
placed in service.
The towers on the three circuits between Leaside station and Hastings
interswitching station were Inspected, all bolts tightened and palnuts installed,
in order to prevent the loosening of the tower bolts by vibration. Along with
this work the conductors on the original circuit were inspected. Underbrushing
was carried out on approximately four thousand acres from a point north of
Oshawa to the Ottawa river.
There were no complete interruptions on the 110, 000- volt transmission
system during the year. There were, however, interruptions on the three
individual groups of this system.
On March 19 a sleet storm of moderate severity caused interruptions to
all customers west of Dundas.
On June 7 a storm of extreme seventy, accompanied by high winds, lightning
and rain, caused extensive damage in many districts between London, Toronto
and Niagara Falls. At this time six towers collapsed on the circuits between
Dundas and Toronto, and six towers on the right-of-way near Stoney Creek.
Damage also occurred to low-tension lines in the Dundas, London, St. Marys,
and Niagara Falls districts.
In addition to the usual patrol, minor maintenance and repair work after
storms, the following maintenance work was carried out on the 110, 000- volt
lines. Some 705 McGuigan type towers, from a point between Dundas and
Guelph, to between London and St. Marys, were cleaned and painted, and the
majority of the towers on the Toronto circuits from Niagara Falls were inspected
and the bolts were tightened. Palnuts were installed on the towers between
Allenburg junction and St. Thomas, and extensions erected on transposition
towers to improve loop clearance. The Archibolt-Brady 60,000-volt towers
between Niagara station and the river crossing were cleaned and painted, also
several 46,000-volt towers, including the towers at the canal crossing in Welland.
m
Extensive underbrushing was done on the older tower lines between Niagara
Falls and Toronto, and westerly as far as St. Thomas. The 110, 000- volt circuits
were re-arranged at our Strachan and York stations and at Saltfleet and Halton
junctions. High-tension insulators were meggered between Kitchener and
London and on other circuits in the vicinity of London. A short section of line
was pladed in service between the Holland Road junction and the Ontario
Paper Company (Steam) transformer station.
A new transformer station of 67,500-kv-a. capacity, along with three
30,000-kw. steam generators, was placed in service at the Ontario Paper
Company on January 29.
The Commission's private telephone service was extended during the year
to the following stations on the Dominion Power division: DeCew Falls,
Hamilton steam plant, Beamsville, Grimsby and Ancaster distributing stations,
22 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
Bartonville switching station, Lincoln Electric Company, St. Catharines, and
the Hamilton field office, thus making telephone communication available
between these points and all other points on the Commission's telephone system.
On the Dominion Power lines there was no total interruption to service
during the year, or any reduction in load due to failure of generation. On the
44,000-volt lines there were two interruptions totalling ten minutes. The violent
storm of June 7 damaged sections of transmission circuits and caused interruptions
to customers in the Brantford, Grimsby, Oakville and Welland areas.
The 44,000-volt pin-type insulators were visually inspected during the year
and all defective units replaced. A portion of the 24,000-volt insulators were
also visually inspected and the defective units changed. Extensive maintenance
work was carried out on the circuits serving Brantford, and these sections are
now in good operating condition. Considerable maintenance work was carried
out on the circuit between Bartonville switching station and Ancaster distribution
station.
Transformation
At Bridgman-Davenport station hand-operated tap changers were installed
on six 5,000-kv-a. high-tension transformers. At Wiltshire station three trans-
formers were sent to the manufacturer for the installation of hand-operated tap
changers, and this same equipment was also installed on thirty-four units at
the station.
The core bracing was inspected and tightened on fifty-three 5,000-kv-a.
transformers during the year.
At Dundas station one 5,000-kv-a. transformer failed in service during the
storm of June 7. There was also a failure of one 1,250-kv-a. unit at St. Thomas.
Both of these units have been rebuilt by the maintenance staff.
A new guided-wave radio transmitter and receiver was installed at Brant
station, and the equipment in Strachan Avenue station was moved to Stratford.
Two complete inspections and overhaul of all outdoor breakers were carried
out during the year, along with one complete inspection of the 110, 000- volt
indoor circuit breakers. In addition to this the regular schedule of inspection
and maintenance was carried out at all high-tension stations.
Distribution
There were no new low-tension transformer stations put in service during
the year, and no changes made in transformer capacity to any of the existing
stations. There were twelve failures of low- tension transformers, ten of which
were rebuilt in the field, and two units were scrapped. A new bank of trans-
formers was installed at Toronto station, replacing three units of similar capacity
which failed in service.
In the Brant district the railway and wire crossings were made standard.
Extensive general overhauling of low-tension lines was carried out in the Preston,
1934
HYDRO-ELECTRIC POWER COMMISSION
23
COKC OVEN
BEACH
— o
Firestone
OH,
NATIONAL CAR
0^1
CAN CRUSHED STONE, DUNDAS. STEEL CO. <
t
gf5f>Wfl|
STEAM PLANT
Van. west cc
^M' ^". \
C0CK5HUTT '
TMl — L
BRANT FORD
□
LEGEND
'.rrLCET RPO (PART)
* \ RCA M 5 Wi LE PRO
■ HOMER
1 1 - ! — ► GRANTHAM R.Pl
«/l>-fS WHEEL
-i—b
BARTONVILLE
id. OCOIY. I 5«.«o I
-H H |*oor«»CT|
□■ycwrK «"«* [J
1— ► SALTFLEET R.PD
GRANTHAM RPD.fPART)
CAN. NIAGARA
±^m [55]
•SALTTLCET R.PD(PAPT)
5T. CATHARINES
HORSEPOWER
SCOTTISH rCRTILIZER
HORSEPOWER AT RATED POWER FACTOR)
IV I SWITCHING STATION
\T)TYl FREQUENCY CHANCER
l^Jrj /7/V TRANSFORMER STATION)
□ DISTRIBUTING STATION
O MUNICIPAL 0R CUSTOMERS STATIONS
STATIONS S LINES IN SERVICE
STATIONS <f £//V£\S /i<pr commission's property
If. Pa RURAL POWER DISTRICT
~o
NIAGARA SYSTEM
DOMINION POWER AND TRANSMISSION
DIAGRAM OF STATIONS
AS »T OCTOBER II. IM3
YDRO-ELECTRIC PO*ER COMMISSION
Stratford, Woodstock, Brant and Kent stations. New air-break switches and
switching structures were erected at Britannia junction and at Beach ville
substation.
In order to obtain a longer life from wood poles, approximately 23,000
poles were uncovered at the ground line, the decayed wood removed, and the
poles given a spray treatment of creosote.
There were no new 26, 000- volt or 13, 000- volt lines placed in service during
the year.
In the Dominion Power division, two 500-kv-a. transformers failed in service
during the year, one at St. Catharines distributing station, and one at the
Beatty-Welland distributing station. Both of these units were rewound and
restored to service. The transformer failure at the Beatty-Welland substation
was caused by lightning, the failure resulting in a fire which destroyed the
station. Equipment was removed to a temporary substation and service was
restored. Transformer stations at Thorold and Humberstone were dismantled,
some of the equipment being salvaged and the balance disposed of. Service to
the Welland Ship canal at lock No. 8, Humberstone guard gate, and lock No. 2
Port Weller, and to the National Fireproof Company, was discontinued during
the year.
24
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
NIAGARA SYSTEM— LOADS OF MUNICIPALITIES, 1931-1932-1933
Municipality
Peak load in horsepower
Oct. 1931 Oct. 1932 Oct. 1933
Change in load
1932-1933
Decrease Increase
Acton
Agincourt
Ailsa Craig
Alvinston
Amherstburg
Ancaster Township.
Arkona
Aurora
Aylmer
Ayr
Baden
Beachville
Belle River
Blenheim
Blyth
Bolton
Bothwell
Brampton
Brantford
Brantford Township.
Bridgeport
Brigden
Brussels
Burford
Burgessville
Caledonia. . . .
Campbellville
Cayuga
Chatham . . . .
Chippawa. . . .
Clifford
Clinton
Comber
Cottam
Courtright . . .
Dashwood .
Delaware . .
Dorchester.
Drayton . .
Dresden . . .
Drumbo. . .
Dublin. . . .
Dundas. . . .
Dunnville. .
Dutton. . . .
East Windsor
Elmira
Elora
Embro
Erieau
Erie Beach
Essex
Etobicoke Township
Exeter
681.7
149.0
147.9
94.2
714.5
277.5
55.3
968.3
490.6
207.6
281.2
329.7
146.8
379.3
93.5
131.7
104.5
2,345.9
9,129.9
530.8
130.2
S3. 3
134.4
143.6
55.2
378.4
27.3
96 2
4,167.0
261.4
63.0
462.4
125.7
69.3
40.7
69.3
37.6
81.7
96.8
319.0
64.2
48.6
1,280.1
786.0
236.8
2,761.4
777.5
411.5
98.5
61.6
11.1
372.1
3,159.5
404.8
787.6
155.2
81.5
87.9
661.6
284.5
52.6
986.6
513.4
161.1
237.9
386.6
124.6
369.9
101.4
118.8
105.2
2,168.2
1,637.9
505.1
108.4
88.4
132.1
136.4
57.1
320.7
26.2
119 9
4,285.0
218.0
58.1
408.8
158.1
62.7
39.4
65.9
41.5
67.0
99.4
286.1
67.7
34.2
1,138
797.1
237.4
2,450.4
646.1
384.7
83.8
70.7
8.0
336.4
3,361.9
424.9
832.6
116.6
88.6
82.8
38.6
"5.r
45.0
0.7
7.2
45.0
7*.i"
616.6
283.8
45.4
1,030.1
43.5
469.1
157.5
241.7
387.4
44.3
3.6
3.8
0.8
119.3
5.3
16.0
14.0
353.9
87.4
137.7
18.9
104.4
0.8
93.0
2,075.2
12,728.7
1,090.8
605.6
100.5
85.5
22.9
89.1
0.7
108.8
23.3
20.9
3.0
115.5
54.1
327.7
7.0
24.2
2.0
7.3
26.9
2.7
112.6
4,258.1
215.3
61.5
3.4
374.5
34.3
164.0
5.9
58.0
4.7
1.0
25.9
6.4
"l2'7
6 1
14
38.4
40.0
35.1
95.7
86.7
28.7
280.0
66.3
42.9
8.7
1,276.1
138.1
907.7
110.6
211.9
25.5
172.7
88.5
93.3
2,277.4
557.6
291.4
104.5
20.7
72.6
1.9
6.4
16
361.9
25.5
3,621.4
382.0
42.9
259.5
1934
HYDRO-ELECTRIC POWER COMMISSION
25
NIAGARA SYSTEM— LOADS OF MUNICIPALITIES, 1931-1932-1933— Continued
Municipality
Peak load in horsepower
Oct. 1931 Oct. 1932 Oct. 1933
Change in load
1932-1933
Decrease Increase
Fergus
Fonthill
Forest
Gait
Georgetown
Glencoe
Goderich
Granton
Guelph
Hagersville
Hamilton
Harriston
Harrow
Hensall
Hespeler
Highgate
Humberstone
Ingersoll
Jarvis
Kingsville
Kitchener
Lambeth
La Salle
Leamington . +
Listowel
London
London Township V.A
Long Branch
Lucan
Lynden
Markham
Merlin
Merritton
Milton
Milverton
Mimico
Mimico Asylum
Mitchell
Moorefield
Mount Brydges
Newbury
New Hamburg
Newmarket
New Toronto
Niagara Falls
Niagara-on-the-Lake
Norwich
Oil Springs
Ontario Agricultural College.
Ontario Central Reformatory
Otterville
686.3
163 6
305.6
6,301.6
889.0
173.2
983.4
93.4
7,794.9
943.7
86,641.1
311.6
368.6
165.5
1,831.4
59.9
384.7
1,915.9
179.9
446.4
15,834.7
107.2
241.3
1,065.9
865.3
27,908.8
311.2
754.1
174.1
83.1
238.6
91.8
2,281 5
705.3
344.5
2,103 1
65.0
500
48.2
89.0
41.8
492.3
1,340.5
5,194.4
9,351.2
536.2
331.7
156.9
401.6
282.8
83.6
652.5
138.5
332.1
6,071.1
902.7
170.8
970.5
90.4
7,710.5
1,046.9
76,409.6
289.2
332.1
150.4
1,864.9
61.6
324.4
1,870
178.7
420.9
14,874.6
99.6
211.5
1,112.6
906.1
29,437.4
371.4
736.0
134.0
74.5
249.3
94.7
2,737.3
597.1
311.4
2,211.8
65.0
422.2
58.2
92.7
43.4
470.2
1,380.7
4,766.7
8,774.0
548.8
335.1
172.7
427.6
249.3
77.7
705.0
133.2
320.6
5,858 7
978.3
163.7
991.9
96.5
7,812.3
418.2
83,832.3
247.2
332.7
121.6
1,879.7
69.0
386.7
1,969
150.1
431.6
15,000.6
94.9
199.0
1,327.0
808.3
30,201.2
358.5
733.9
136.0
66.3
211.8
66. 7*
2,765.1
804.4
295.6
2,218.5
100.0
433.8
45.5
79.6
40 6
399.1
1,285 5
4,790 8
9,135.6
546.1
308.3
159.3
469.1
243.9
84.3
5.3
11.5
212.4
" 7 '. i
628.7
42'0
28'8
28.6
4.7
12.5
97
12.9
2.1
8.2
37.5
28.0
15.8
12.7
13.1
2.8
71.1
95.2
2.7
26.8
13.4
5.4
52.5
75.6
21.4
6.1
101.8
7,422.7
"6!6
14.8
7.4
62.3
99.0
10.7
126.0
214.4
763^8
2.0
27.8
207.3
6.7
35.0
11.6
24.1
361.6
41.5
6.6
26
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
NIAGARA SYSTEM— LOADS OF MUNICIPALITIES, 1931-1932-1933— Continued
Municipality
Peak load in horsepower
Oct. 1931 Oct. 1932 Oct. 1933
Change in load
1932-1933
Decrease Increase
Palmerston
Paris
Parkhill
Petrolia
Plattsville
Point Edward
Port Colborne
Port Credit
Port Dalhousie. . . .
Port Dover
Port Rowan
Port Stanley
Preston
Princeton
Queenston
Richmond Hill . . . .
Ridgetown
Riverside
Rockwood
Rodney
St. Catharines
St. Clair Beach
St. George
St. Jacobs
St. Marys
St. Thomas
Sandwich
Sarnia
Scarboro Township.
Seaforth
Simcoe
Springfield
Stamford Township
Stouffville
Stratford
Strathroy
Sutton
Tavistock
Tecumseh
Thamesford
Thamesville
Thedford
Thorndale
Thorold
Tilbury
Tillsonburg
Toronto
Toronto Township.
Walkerville
Wallaceburg
Wardsville
Waterdown
Water ford
Waterloo
518.9
1,242.0
140.7
731.4
60.8
267.4
1,608.6
537.5
457.1
315.2
74.2
220.9
3,128.6
101.3
87.1
317.3
416.9
1,212.7
104.5
145.6
8,449.7
97.6
92.5
140.2
1,521.9
5,643.4
3,459.3
6,801.6
3,034.8
510.9
1,491.1
52.9
1,831.1
194.7
7,790.6
1,000.0
150.4
523.6
443.8
154.1
178.3
60.8
46.1
1,941.7
321.7
884.7
289,262.7
1,668.1
6,348.5
1,059
38.0
231.9
380.0
2.946.2
458.5
1,178.4
131.3
761.7
53.3
689.0
1,407.5
549.3
439.7
315.6
73.0
228.5
2,560.3
103.2
83.5
297.0
439.7
1,200.6
104.5
145.7
7,872.8
90.7
147.4
152.8
1,501.8
5,761.4
2,996.4
7,360.6
3,124.6
465.3
1,546.1
65.6
1,859.8
204.1
7,180.2
910.2
152.7
496.0
302.2
158.8
171
57
40
1,956
366
891
6
6
4
6
280,795.0
1,868.0
5,454.7
1,252.0
35.4
191.7
406.8
2,660.8
437.5
1,197.2
124.2
685.8
60.2
636.7
1,420.9
611.2
503.7
296.5
67.1
261.5
2,461.1
98.8
80.7
293.1
446.4
1,104.9
89.8
131.1
7,854.2
72.6
129.3
151.4
1,225.7
6,179.6
2,956.2
7,581.1
2,981.5
408.8
1,613.9
59.0
1,819.0
167.9
6,530.9
946.4
153.5
424.6
294.7
159.5
163.5
127.0
36.4
1,914.6
398.1
900.1
269,144.8
1,793.7
5,336.4
1,888.7
34.3
201.0
399.4
2,668.9
21.0
7.1
75.9
52.3
19.1
5.9
99.2
4.4
2.8
3.9
95.7
14.7
14.6
18.6
18.1
18.1
1.4
276.1
40.2
143.1
56.5
6.6
40.8
36.2
649.3
71.4
7.5
7.5
4.2
41.8
11,650.2
74.3
1183
1.1
7.4
18
8
6
9
13
4
61
9
64
33.0
6.7
418.2
220*5
67.8
36.2
0.8
0.7
69^4
31.5
9.1
636.7
"9.3
"s.'i
1934
HYDRO-ELECTRIC POWER COMMISSION
27
NIAGARA SYSTEM— LOADS OF MUNICIPALITIES, 1931-1932-1933— Concluded
Municipality
Peak load in horsepower
Oct. 1931 Oct. 1932 Oct. 1933
Change in load
1932-1933
Decrease Increase
Watford
Welland
Wellesley
West Lome
Weston
Wheatley
Windsor
Woodbridge
Woodstock
Wyoming
York, East Township. .
York, North Township
Zurich
200
4
3,967
8
142
7
97
8
2,619
2
155
7
25,431
8
293
5
4,781
5
60
3
5,138
2,757
4
85
9
186
3
3,576
4
97
7
105
9
2,453
1
143
1
23,029
9
247
9
4,785
5
64
6
5,504
2,829
7
76
4
185
3,918
2
94
7
98
6
2,790.8
123
7
0,550
3
261
4
4,950
4
75
2
5,330
7
2,890
64
8
1.3
3
7
3
19
2,479
4
6
173
3
11.6
341.8
337.7
13.5
164.9
10.6
60.3
NIAGARA SYSTEM— RURAL POWER DISTRICT LOADS, 1931-1932-1933
Municipality
Peak load in horsepower
Change in load
1932-1933
Oct. 1931
Oct. 1932
Oct. 1933
Decrease
Increase
Acton. . .'
10.0
5.6
3.2
518.8
304.8
32.0
293.0
1,072.2
269.9
153.5
840.7
102.7
127.3
565.2
35.7
145.3
260.5
434.0
109.9
124.6
297.2
335.9
28.5
64.6
552.3
29.0
115.7
10.0
5.6
3.2
533.7
294.4
42.5
398.6
1,061.1
254.9
1 43 . 6
897.2
115.6
133.3
464.9
38.0
155.9
322.0
441.3
102.2
125.2
265.3
329.4
34.6
79.2
578.3
42.0
122.8
10.0
5.6
3.2
496.7
291.1
42.5
367.1
1,030.7
220.0
118.5
926.4
89.0
130.0
434.4
31.5
170.5
300.5
473.5
99.2
121.7
299.5
269.2
42.2
59.0
582.6
42.0
126.0
Ailsa Craig
Alvinston
Amherstburg
37.0
3.3
Aylmer
Ayr
Baden
31.5
30.4
34.9
25.1
Beamsville
Belle River. . . .
Blenheim
Bond Lake. .
29.2
Bothwell
26.6
3.3
30.5
6.5
Brampton
Brant
Brigden
Burford
14.6
Caledonia. .
21.5
Chatham
32.2
Chippawa
3.0
3.5
Clinton
Delaware
34.2
Dorchester
60.2
Dresden ....
7.6
Drumbo. . . .
20.2
Dundas. . . .
4.3
Dunnville.
Dutton .
3.2
28
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
NIAGARA SYSTEM— RURAL POWER DISTRICT LOADS, 1931-1932-1933— Continued
Municipality
Peak load in horsepower
Oct. 1931 Oct. 1932 Oct. 1933
Change in load
1932-1933
Decrease Increase
Elmira
Elora
Essex
Exeter
Forest
Gait
Georgetown
Goderich
Grantham Township
Guelph
Haldimand
Harriston
Harrow
Ingersoll
Jordan
Keswick
Kingsville
Listowel
London
Lucan
Lynden
Markham
Merlin
Milton
Milverton
Mitchell
Newmarket
Niagara
Norwich
Oil Springs
Palmerston
Petrolia
Preston
Ridgetown
St. Jacobs
St. Marys
St. Thomas
Saltfleet
Sandwich
Sarnia
Scarboro Township.
Seaforth
Simcoe
Stamford
Stratford
Strathroy
Streetsville
72.7
139.8
213.9
217.6
28.0
179.6
132.4
71.5
643.2
392.1
193.2
22.1
399.4
370.6
200.0
291 1
526.6
113.9
1,451.8
65.3
160.0
387.7
157.5
124.8
74.5
190.4
290.3
598.9
207.7
45.5
31.5
25.3
848.1
284.2
241.9
243.6
465.0
1,114.6
1,008.3
491.1
315.0
46.3
175.0
193.0
176.1
96.6
376.2
79.6
105.7
201.0
245.5
28.0
197.9
134.8
84.0
527.1
415.5
240.0
23.9
345.1
329.8
320.0
381.6
545.8
131.9
1,509.0
64.6
177.2
453.0
175.2
128.2
69 5
187.8
255.7
434.5
202.3
44.9
37.5
25.3
848.2
260.8
218.5
210.4
469.3
1,029.9
1,001.9
466.4
296.6
47.8
231.0
185.1
164.9
95.0
324.3
70.2
98.2
189 6
235.3
28.0
181.3
124.9
84.2
611.1
411.5
164.0
20.0
323.6
337.8
282.0
395.8
453.5
132.7
1,523.7
60.2
166.5
423.8
177.5
140.0
65.5
172.2
225.3
395.9
241.3
45.5
48.0
25.3
854.7
227.9
268.8
183.8
483.2
966.1
908.0
485.3
358.4
53.2
205.4
156.5
104 6
93.2
251.1
9.4
7.5
11.4
10.2
16.6
9.9
4.0
76.0
3.9
21.5
38.0
92.3
4.4
10.7
29.2
4.0
15.6
30.4
38.6
32.9
26.6
63.8
93.9
25.6
28.6
60.3
1.8
73.2
934
HYDRO-ELECTRIC POWER COMMISSION
29
NIAGARA SYSTEM— RURAL POWER DISTRICT LOADS, 1931-1932-1933— Concluded
Municipality
Peak load in horsepower
Change in load
1932-1933
Oct. 1931
Oct. 1932
Oct. 1933
Decrease
Increase
Tavistock.
165.7
105.9
78.1
321.3
180.5
128.7
84.5
830.5
129.2
17.6
1,115.3
561.9
480.6
194.4
100.9
119.4
302.4
179.8
150.8
70.7
906.5
158.2
16.4
1,161.8
550.0
487.4
153.6
108.6
134.6
314.4
173.1
144.3
82.8
676.2
174.9
22.0
1,079.1
537.9
483.3
40.8
Thamesville
7.7
Tilbury
Tillsonburg
15.2
12.0
Wallaceburg
6.7
6.5
Walsingham
Walton .
12.1
Waterdown
230.3
Waterford
16.7
Watford . .
5.6
Welland
82.7
12.1
4.1
Woodbridge
Woodstock
GEORGIAN BAY SYSTEM
The Georgian Bay system peak and average loads both show a decrease
of approximately three per cent compared with last year and this is almost
entirely due to the reduced demands in the Midland areas, plus the loss of
considerable load owing to two large stone crushing plants closing down for the
greater part of the year.
Storage water reserves on the system were considerably below normal
toward the latter part of the year, due to the exceedingly hot summer combined
with a long period of low precipitation, and stream flows were reduced to such
an extent that from July until the end of the year it was necessary to supply a
large amount of power from the Niagara system, through the Hanover frequency
changer set, in order to conserve water for plant operation over the winter
period. Assistance was given to the Orillia Water, Light and Power Commission
during this period, as Orillia's plant at Swift rapids was unable to carry its
load due to reduced flows in the Severn river.
A new 22, 000- volt transmission line was built from a point on the old line
about two miles west of Shelburne, south, to intersect the old line running west
to Grand Valley. From the point of intersection, east to the former Grand Valley
junction, the old line was restrung with larger conductor and a new line built
from this point to Orangeville. The new line was required as the old line was
of insufficient capacity to carry the increased loads and provide proper voltage
regulation.
On March 19 and 20, shortly after the new line was olaced in service, a
severe sleet storm in the area between Dundalk and Orangeville caused heavy
30 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
damage to telephone, telegraph and power lines. The excessive weight of sleet
on wires and cables caused a number of breaks, particularly on the telephone
lines, which hindered restoration of service. It was especially gratifying that the
new line was completed prior to the sleet season as this storm would in all
probability have caused serious damage to the old line.
The 4,000-volt line between Grand Valley and Arthur was rebuilt.
Approximately one hundred new poles were erected, the line was resagged,
poles straightened and a number of guys added.
Special inspection was made and defective crossarms, insulators and pins
replaced on lines from Eugenia powerhouse to Collingwood, from Hanover to
Chesley and Paisley, from Big Chute powerhouse to Waubaushene, from
Waubaushene to Elmvale and from South Falls powerhouse to Huntsville.
To conform with specifications of the Board of Railway Commissioners
for Canada, the power lines at railway and telephone crossings were reinforced
on line sections from Eugenia generating station to Owen Sound, from Eugenia
generating station to Durham and Mount Forest, from Flesherton to Shelburne,
from Fergusonvale to Collingwood, from Big Chute generating station to
Waubaushene, from Waubaushene to Barrie and all south of Barrie, also all
lines in Wasdells district.
To accommodate changes in highway locations, a number of poles were
moved or lowered between Kilsyth and Tara, between Waubaushene and
Midland, between Waubaushene and Elmvale and between Barrie and Bradford.
All poles in the section of transmission line between Gamebridge and
Kirkfield and in all line sections of the Wasdells district south of Cannington,
received treatment at the ground line with preservative.
Over the whole system, 153 poles were reinforced by the addition of stubs
and 21 poles were replaced.
At Eugenia Falls plant, improvements were made in the station grounding
to bring it up to standard and the 60-cell storage battery was replaced with a
new battery. The timber in the trestle under No. 1 pipe line east of the surge
tanks was replaced by the Operating department, and the Construction depart-
ment placed a culvert under the No. 1 and No. 2 pipe line trestles along with
a fill of rock, gravel and earth. Repairs were made to No. 3 unit draft tube
quarter turn, also to the turbine runner and shaft. The work on the draft tube
quarter turn and on the runner was done at the Commission's machine shop at
Niagara Falls. This involved building up eroded sections by welding and altering
the downstream clearance ring. A forged steel sleeve for the shaft at the stuffing
box was supplied to replace the defective bronze sleeve and the necessary machine
work was done at Eugenia Falls powerhouse. No. 1 and No. 2 turbines were
also inspected but only minor repairs were necessary.
At Walkerton generating station dam, repairs were made by the Construction
department, which included the driving of sheet piling to form a cut-off wall to
correct leaks under the centre portion of dam, provision of fills on the upstream
1934
HYDRO-ELECTRIC POWER COMMISSION
31
HORSEPOWER
HORSEPOWER
^5ini i§55iglSlSlig§i5i8I5lS i^glS§i8gglSilgl8J§i8lglSlll l5§§L
30.000 -n M I I I I I I 1 I ' I 1 I I I I I I I I I I I 1 I I I I I I I I I I 1 I II I I | I | | i ll I M I 30.000
25.000
20,000
15,000
10,000
5,000
fsllliiilsl
i8lllNiliigliSiiSi^isii§|igliii^ii§i§
NOTE: — The Georgian Bay system includes the Severn, Eugenia, Wasdells, Muskoka and Bala districts.
In the diagram the load for the Muskoka, district is not included until November, 1924. Details
respecting this load for preceeding years are given in earlier Annual Reports. The load of the
new district at Bala is not included in above graph until April, 1931, previous meter records
being incomplete
side to prevent scouring, and the construction of rock-filled timber cribs on the
downstream side at the east end of the dam, to divert the water and prevent a
washout of the shore. While this work was proceeding, excessive flows developed
in the river and required that a large flow be allowed to pass through the waste
sluice at Walkerton plant. The action of the water started to scour the earth
bank at the north-west corner of the powerhouse on the tailrace side. To protect
the bank, it was necessary to construct a bench type timber crib with wood
sheet piling on the side next the water. The crib was filled with rock and gravel.
At Walkerton plant, which was shut down while repairs to the dam were in
progress, an inspection was made of the turbines and hydraulic equipment and
minor adjustment and repairs were made. The 2,300-volt tie line was rearranged
to provide greater safety.
32 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
At Hanover generating station dam, bad leaks developed at the junction of
the old and new sections November 7, 1932. Examination revealed that pond
water had scoured a channel under a bulkhead wall where it joins the north wall
of the main sluice section. Repairs consisted of driving necessary piling to cut off
any flow of water under the bulkhead, the underpinning of bulkhead to ensure
its stability, erection of a protective crib, and the restoration of original fills.
By agreement, this dam was later turned over to the town of Hanover as the
town is interested in the maintenance of this dam to provide a supply of water
for its pumping station. Water can still be secured for the operation of the
Commission's hydraulic plant when required, limited only by the natural river
flow, and a certain reserve for pumping plant operation.
At Hanover generating station, repairs were made to the concrete wing
wall on the north side of the intake canal adjacent to the plant. The concrete
had become defective and excessive leaks developed.
At Hanover frequency-changer station, operation for the past year was very
satisfactory and no special maintenance work was required.
At Big Chute generating station, the No. 1 transformer room and the low-
tension room were painted. The field and armature coils of all machines were
painted with insulating paint. No. 1 oil pump for supplying oil pressure to the
governor system, which had given trouble, was redesigned, and after being placed
in operation gave complete satisfaction. A number of decayed stop logs in the
main dam were replaced with new logs. All hydraulic equipment was inspected
and minor adjustments made.
At Wasdells generating station, septic tanks and disposal beds for the
superintendent's house and the generating station were constructed and the
domestic water supply for the superintendent's house and powerhouse was re-
arranged. In conjunction with this work, improvements to the grounds around
the plant were carried out. The bearings in the No. 2 unit were removed because
of wear and were rebabbitted.
At South Falls generating station, owing to a failure of the screws holding
the shaft cap, which in turn holds the thrust ring in place on the upstream end
of No. 3 unit shaft, a change in design was decided upon and alterations were
made to both No. 1 and No. 3 units, which are of similar construction, to guard
against further trouble from this source.
At Hanna Chute and Trethewey Falls generating stations, routine inspections
of machines, buildings and water controlling structures were made, and only
minor repairs were necessary.
At Owen Sound distributing station, improvements were made to station
grounding in order to bring the grounding layout up to standard.
At Chatsworth distributing station, all 22,000-volt bus insulators were
replaced, as they had given evidence of having served their useful life.
At Shelburne distributing station, the high-voltage and low-voltage entrance
structures were redesigned and a new airbreak switch was erected on the high-
voltage line. Grounding connections were also improved.
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LEGEND
[~~ j CEHERATINC_ STATIONS^
rXfl SWITCH ma STATIONS
|C5xJ] EREQVEHCr CHANCER
i | OISTRIBUTINC STATIO
o
vrj /« SERVICE
GEORGIAN BAY SYSTEM
(6Q CYCLES)
DIAGRAM OF STATIONS
AS AT OCTOBER 31. 1932
1934
HYDRO-ELECTRIC POWER COMMISSION
33
At Berkeley distributing station, during a severe lightning storm on June
7, one low-voltage and two high-voltage transformer bushings were destroyed;
these were replaced with new bushings.
At Kincardine distributing station, in order to provide for an increase in
load due to a new power consumer, three 125-kv-a. transformers were removed
and replaced with three 250-kv-a. transformers.
At John E. Russell Company distributing station, Durham, one 150-kv-a.
transformer failed in service October 16, and repairs were made at the manu-
facturer's factory.
Walkerton rural distributing station, which is located at Walkerton
generating station, was placed in service October 20, 1932. This distributing
station was completed January 24, 1932, but could not be placed in service
until Mildmay distribution system was changed to 4,000 volts.
At Gravenhurst and Huntsville distributing stations, improvements were
made in grounding of equipment to bring grounding layouts up to standard.
GEORGIAN BAY SYSTEM— LOADS OF MUNICIPALITIES, 1931-1932-1933
Municipality
Peak load in horsepower
Change in load
1932-1933
Oct. 1931
Oct. 1932
Oct. 1933
Decrease
Increase
Alliston
199.6
130.7
121.0
2,503.4
295.6
134.7
138.2
59.0
290.0
155.5
51.7
406.9
290.9
1,458.3
52.5
107.2
145.1
627.3
145.4
63.8
227.9
128.9
118.0
2,381.1
216.4
106.6
134.9
56.3
320.0
161.9
53.2
407.5
257.3
1,339.9
59.0
121.4
148.8
392.1
147.4
65.1
198.0
132.7
120.0
2,195.6
179.7
114.3
140.0
45.4
263.4
152.8
61.2
464
234.6
1,293.8
52.9
96.0
163.0
712.3
148.8
51.3
29.9
Arthur
3.8
Bala
«$
2.0
Barrie
185.5
36.7
Beaverton
Beeton
7.7
Bradford
5.1
Brechin
10.9
56.6
9.1
Camp Borden
Cannington
Chatsworth ....
8
Chesley
56.5
Coldwater
22.7
46.1
6.1
25.4
Collingwood
Cookstown
Creemore
Dundalk
14.2
Durham
320.2
Elmvale
1.4
Elmwood
13.8
34
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
GEORGIAN BAY SYSTEM— LOADS OF MUNICIPALITIES, 1931-1932-1933— Continued
Municipality
Peak load in horsepower
Oct. 1931 Oct. 1932 Oct. 1933
Change in load
1932-1933
Decrease Increase
Flesherton
Grand Valley . . . .
Graven hurst
Hanover
Hepworth
Holstein
Huntsville
Kincardine
Kirkfield
Lucknow
Markdale
McTier
Meaford
Midland
Mildmay
Mount Forest . . .
Neustadt
Orangeville
Owen Sound
Paisley
Penetanguishene .
Port Carling
Port Elgin
Port McNicoll.. .
Port Perry
Priceville
Ripley
Rosseau
Shelburne
Southampton
Stayner
Sunderland
Tara
Teeswater
Thornton
Tottenham
Uxbridge
Victoria Harbour
Victoria Road . . .
Walker ton
Waubaushene. . .
Wiarton
Windermere
Wingham
Woodville
87.0
121.1
622.0
1,002.7
24.1
20.9
1,023.5
434.8
31.0
222.5
163.3
148.0
431 6
2,723.7
63.1
358.4
33.5
550.3
3,202.4
113.1
552.3
126 .0
195.7
99
211.9
15.7
55.4
30.0
235.8
233.2
193.7
59.0
84.1
134.8
23.4
55.7
199 8
64.3
10.3
492.2
52.9
238.3
25.0
304.6
65.1
79.8
123.8
574.0
1.042.9
24.1
18.7
1,047. C
407 . 5
28.6
187.0
149.4
145.0
394
3,345
66
328.4
30.0
621.0
3,338.5
114.4
561.1
128.0
201.8
90.2
179.8
16.0
58.9
35.1
197.9
235.9
203.2
63.0
87.7
114.9
18.3
64.3
205.8
76.4
10.0
419.9
58.3
220.1
31.0
209.3
61.0
75.9
3.9
15 5
108.3
672.5
98.5
910 4
132 5
25.7
1.6
16 6
2.1
91 2
955 . 8
564.3
156.8
22.8
5.8
222.5
35.5
179.4
30.0
111.0
34.0
395.4
0.7
2,408.6
937
71.5
4.8
329.5
1.1
34.0
4.0
585.4
35.6
261.5
3,077.0
118.6
4.2
658.7
97.6
105
23.0
262 . 5
60.7
83.5
6.7
23.2
156.6
16.7
0.7
60.3
1.4
30.0
5.1
5.0
30.0
33.9
3.0
5.5
2.5
0.4
2 1
3.6
192.9
205.9
169 3
60.0
82.2
112.4
17 9
62.2
202.2
77.3
"0.9'
10.0
463.1
43.2
56.3
232.2
2.0
12 r
33.0
2.0
290.5
81.2
55.2
5.8
Note: Formosa absorbed by Bruce R.P.D.
Hornings Mills absorbed by Shelburne R.P.D.
1934
HYDRO-ELECTRIC POWER COMMISSION
35
GEORGIAN BAY SYSTEM
-RURAL POWER DISTRICT LOADS, 1931-1932-1933
Rural power district
Peak load in horsepower
Change in load
1932-1933
Oct. 1931
Oct. 1932
Oct. 1933
Decrease
Increase
Alliston. . .
92.2
3.2
56.0
196.3
107.1
3.2
61.0
220.7
36.2
85.8
157.3
2.0
46.7
61.1
13 .
44.0
10.3
0.8
56.2
72.4
7.3
37.2
84.1
20.0
162.2
151.4
20.9
17.0
19.0
30.3
33.1
10.0
121.8
10
8.8
21.1
119.8
54.0
12.7
35.0
104.5
92.5
99.5
69.3
3.2
93.0
233 4
45.5
110.0
137.6
5
42.8
103.3
12.0
35.7
8.9
0.8
55.0
66.3
8.0
27.7
93.4
48.2
191 7
136.2
33.4
21.0
21.0
28.1
34.9
53.0
141.0
10 3
12.3
29.3
124.1
50.0
16.3
43.9
105.1
114.6
106.2
37.8
Arthur
Bala
32.0
Barrie
19^7
12.7
Baysville
9.3
Beaumaris
83.1
47.2
24.2
Beaverton
Beeton
3.0
Bradford
20.0
50.3
12.0
41.5
9.8
0.8
20.1
63.2
5.5
32.1
56.3
14.0
135.4
151.4
2.0
11.0
14.0
29.6
35.5
8.0
103.1
10.0
8.0
9 6
98.4
45.7
12
24.0
102.5
76.0
104 2
3.9
Bruce
42 2
Buckskin
1.0
8.3
1.4
Cannington
Chatsworth
Cookstown
Creemore
1.2
6.1
Elmvale
Flesherton
0.7
Gravenhurst
9.5
Hawkestone
9.3
Huntsville
28.2
Innisfil
29.5
Mariposa :
15.2
Markdale
12.5
Medonte
4.0
Midland
2.0
Nottawasaga
2.2
Orangeville
1.8
Owen Sound
43.0
Port Perry
19.2
Ripley
0.3
Sauble
3.5
Shelburne
8.2
Sparrow Lake
4.3
Tara
4.0
Thornton
3.6
Utterson
8.9
Uxbridge
0.6
Wasaga Beach
22.1
VY roxeter
6.7
Note: Georgina R.P.D. absorbed by Beaverton R.P.D.
Cannington R.P.D. includes what was formerly known as Cannington R.P.D. No.
1 and No. 2 districts.
36 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
EASTERN ONTARIO SYSTEM
The load on the Eastern Ontario system continued at a slightly lower level
during the earlier months of the fiscal year. However, beginning with the month
of April, a gradual improvement began and continued until the end of the year.
The peak demand for the month of October exceeded the peaks for the corres-
ponding months of 1931 and 1932 and almost equalled the peak of 1930 which
is the maximum peak on record for this month. The kilowatt-hours used in
the month of October are the maximum recorded for the month of October in
any year.
District Load Conditions
In the Central Ontario district the load showed signs of an underlying
improvement about the end of February, the downward trend of the load being
less than usual for the season. During subsequent months the improvement
became more evident. By June the load had recovered all lost ground, and
thereafter continued to exceed the loads of the corresponding months of the
previous year, with a slight exception in September. The peak load for the
month of October shows an increase of more than six per cent over, the peak
for the corresponding month of 1932.
A survey of the municipal and industrial loads in this district indicates a
rising tendency during the latter months of the year. It should be noted that
one large industrial customer who was taking a load of more than 3,000 horse-
power in October, 1932, has not operated throughout the year 1933. If this
customer is left out of consideration when analyzing the load trend in the
remainder of the district, it will be evident that there has been a definite
improvement in load conditions in the Central Ontario district during the
latter part of 1933.
The Ottawa district load maintained approximately the same level on peak
as in 1932 until early in September when the load showed a slight increase which
continued into October. The monthly average loads show a slight decrease but
approximate those of the two previous years. It will be noted that the monthly
peak loads in this district have continued to show, with few exceptions, increases
over the corresponding months of the previous years. This is primarily due to
the fact that the industrial load, which has suffered the greatest losses as a result
of the depression, represents only a small percentage of the total load in this
district. It also indicates that the residential and commercial load has made
increases which more than off-set any industrial decreases.
The St. Lawrence district load was someuhat irregular during the earlier
months of the year, but was consistently higher than the 1932 peak loads after
the month of March. The 1933 peak-load curve crossed the 1931 curve early
in the month of July and continued to show an increase until the end of the
year. The peak demand for the month of October exceeded the maximum
monthly peak on record for this district.
1934
HYDRO-ELECTRIC POWER COMMISSION
37
HORSEPOWER
1
JAN '
FEB
MAR
APR
MAY
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
JAN
FEB
MAR
APR
MAY
JUNE
JULY
SEPT
OCT
NOV
DEC
JAN
FEB
MAR
APR
MAY
JUNE.
JULY
AUC
SEPT
OCT
NOV
DEC
FEB
MAR
APR
MAY
JUNE
JULY
AUC.
SEPT
OCT
NOV
DEC
JAN
FEB
MAR
APR
MAY
JUNE
JULY
SEPT
OCT
NOV
DEC
IDU.UUU
1QOO f* . / \ #■-»
1933 / > r \_. / \ . / "\
\....jr s ..„ /-—ji\t—- _:-:\ y L__p = P i_
<^-'>? i - '>-■>/ * w v \/
^ J- loon. 1Q^1 -1Q^9
^ / iyju iyji ii7o£
Trr i yzy
1 q on
i y^o
EASTERN ONTARIO SYSTEM _ _
PEAK LOADS
FOR ALL DISTRICTS COMBINED
HYDRO-ELECTRIC POWER COMMISSION
I I ! I II I I I I I l II II I II I I I I I I ! ! I I II I I
e
JAN
FEB
MAR
APR
MAY
JUNE
AUG
SEPT
OCT
NOV
DEC
FEB
MAR
APR
JUNE
AUG
SEPT
OCT
NOV
DEC
JAN
FEB
MAR
APR
JUNE
AUG
SEPT
OCT
NOV
DEC
FEB
APR
MAY
JUNE
AUG
SEPT
OCT
DEC
JAN
FEB
MAR
APR
MAY
JUNE
AUG
SEPT
OCT
NOV
DEC
HORSEPOWER
I50.0CO
100,000
50,000
The monthly average loads on the St. Lawrence district showed a slight
decrease during the months of January and February in comparison with the
corresponding months of 1932, but were almost identical with those of 1931.
However, the average load for the month of March exceeded the average load
recorded during any previous month, and the load continued to increase until
the end of the year. While certain of the municipalities and industrial customers
show an increase on both peak and average load, one large industrial customer
was chiefly responsible for the increase shown by the district as a whole.
The Rideau district has maintained approximately the same levels on both
peak and average loads as in 1931 and 1932.
The Madawaska district load conditions were slightly below the 1932 level
during the earlier months of the year but made a recovery in the early part
of July and continued to show a slight increase until the end of the year.
38
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
HYDRO- E.H.CTR1C POWE.R C0MM155ION OT ONTARIO
Graphs Shewing
PRECIPITATION on she OTONABK WATERSHED
1933
TK* Actual sad Normal
Ike oumtritel lol*k of t»iui
Dm Normal Rttipl^hcp far
iptoijon [*aur»j thown in 111'
[mm lii» t»ur jletiom
Jk Month H the wttttt
jrc:
OVtr a period <f y*0r>.
TV* Upper Oreoi e»mi« Ike Ach»! Mwtilly FWctptisW it a fcseaiaqt
of Ik. Normal PretlpSl.llon f«r ttiel nonlh «nd .« Int msrlMy oemwk differ,
ff does ftd relate fcne meuln fo enoiher.
TK. tower Graplu iU tke Adtwl and NotmiI R-rtij>iWfcm m tocbes »f rain.
% 80
60
40
20
■~7T
.05. PIBCgNX. <K_HSSMAL.
160
140
120
W& too
*F\
'eruniafie of Normal rVecipila}i<
80 %
I
60 1
-40 Z
'C
j
20. .
014
12
10
inches (Nornwi) Prsdpiiatior.
14.
Iticheft (Actual) Precipitation
stations:- t- Ptterbonj
2- Lindsay .
3- Ap»l«y
4- Bancroft
Mi
1933 Jan. Feb. Mar. Apr- j May I Jun* July ; Auo,. \ Septr Oct j Nov.
Dtc. 1933 i
PLATE A— PRECIPITATION DATA— 1933
The upper graph represents the estimated actual monthly precipitation on the Otonabee
watershed expressed as a percentage of the normal precipitation.
The estimate is based upon the actual and normal return of the Meteorological Service
for Peterboro, Lindsay, Bancroft and Haliburton.
Although the numerical values differ from month to month the normal precipitation is
taken as 100 per cent, hence the solidly hatched areas represent the amount by which the
precipitation exceeded the average while the dotted hatched area represents in a similar
manner the deficiencies.
The lower graph shows the actual and normal precipitation in inches of rain
Graph No. 3— Average daily wastage at all H.E.P.C. plants. In the weekly aggregate the area under
this graph equals the wastage represented by the dotted hatched area between curves
2 and 1a.
Graph No. 5 — Midnight elevations of Rice Lake.
Graph No. 6— Midnight elevations of Heely-Hastings reach.
*Operating week changed to end Sunday midnight instead of Friday midnight. The period shown
ending December 1st covers two days only.
934
HYDRO-ELECTRIC POWER COMMISSION
39
If-
3WO- £l£GTb t Q .°i3fv'«? ' C0Ma4>33IOK.. Or ov:
■■CJuhaf : Onttrric Qisfrlil-
VOLS' „
»i.*j||
j»i iJua..
if*
S'l
III
pi
j: ■ \
sdo-o.io.c .1
III
>99 a; t'6. J ',
-■ v
/\
yvj. ;
f: . : f|
' ■ V
fcacoa ._
f y
■;MC£ lA^t 3.£WT«ShS
W a W^^vv^:-
piUiffii-j
13
f*
mi
ssus » * i « is i! w } tt
» 2J *> 7 14 It 2S
Apr- . , [MdJ- ;
•5 I » K 3 K i B •» 77 t 'J B H
.'\toty Au^t Sepfc
XI 29 5 S 19 ' -J* "3 B «9f
PLATE B— GENERAL OPERATING DATA
December 16, 1932, to December 20, 1933
Notes for Eastern Ontario District General Operating Data Curves
Graph No. 1 — System average weekly load in kilowatts which includes power purchased from the
Gatineau Power Company.
Graph No. 1a — Weekly average load in kilowatts supplied by H.E.P.C. plants on the Trent and
Otonabee rivers.
Graph No. 2 — Weekly average power equivalent of total flow at all H.E.P.C. Plants. This equals the
weekly average load supplied by these plants, plus the power equivalent of the weekly
average wastage at these plants. This wastage is shown by the dotted hatched area
between curves 2 and 1a.
{Explanation continued on page 38, facing)
40 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
Stream Flow — Trent River
Stream flow in the Trent river, from which the Central Ontario district
obtains the greater part of its power supply, showed a heavy surplus over power
requirements during the first seven months of the fiscal year due to the heavy
precipitation experienced in the late summer and fall of 1932, and during the
first part of the winter months of 1932-33. However, from the beginning of
May, 1933, until the end of October, rainfall was consistently below normal,
excepting the month of August, with the result that very critical periods
of low stream flow were experienced during the months of September and
October. Some of the weekly average flows experienced during this time
were even lower than those experienced in 1931, and represent the lowest
on the Commission's records, which date back to 1916. The capacity of
the Commission's generating stations on the Trent river was very seriously
reduced during these periods of low stream flow. The weekly average available
capacity of these generating stations during the week of minimum stream flow
amounted to only 11,720 horsepower, and this, in terms of the district weekly
load factor, gives a peak capacity of 18,000 horsepower, or a reduction in peak
capacity of approximately 35,000 horsepower. Serious load reductions would
have had to be made had not the supply of Gatineau power been available.
Generating Stations
Continuing the same plan of operation followed in 1932, as mentioned in
the previous issue of this Report, Plant No. C-30 at Fenelon Falls and Plant
No. C-5 at Frankford in the Central Ontario district, and Galetta generating
station in the Madawaska district, were maintained throughout the year on a
standby basis.
During the year the usual programme of station and line maintenance
work was carried out. An outline of the work done is given in the following
paragraphs.
At Sidney, plant No. C-2, the four main turbines and the exciter turbine
were unwatered. Inspection indicated that no extensive maintenance work was
necessary. The lower guide bearings on two of the main turbines were rebabbitted.
All governors were dismantled and thoroughly cleaned ; defective bearings being
replaced where necessary. All the low-tension oil-breakers were overhauled.
Three defective bushings were replaced on one of the generator 10,000-volt
oil-breakers. The direct-current cables to all generators were replaced. All the
power-house floors and the walls and ceiling of the thrust deck were painted.
The entire roof of the power house was treated with a roofing compound.
At Frankford, plant No. C-5, no extensive maintenance work was found
necessary. One turbine was overhauled. The low-tension electrolytic lightning
arresters were overhauled. The core wall between the tail race and the river
was repaired. This plant was maintained on a standby bass during the year
and was only placed in operation on occasions when the additional capacity was
required.
1934 HYDRO-ELECTRIC POWER COMMISSION 41
At Meyersburg, plant No. C-8, all turbines were unwatered and inspected
and the racks were cleaned. The governors were overhauled and painted. All
the high-tension oil-breakers were overhauled. One defective 44,000-volt bushing
was replaced in the station service oil-breaker.
At Hagues Reach, plant No. C-9, all turbines were unwatered and inspected
and the racks were cleaned. The bearings of one turbine were tightened. A
quantity of debris was removed from the wheel pits. The governors were
overhauled and painted. One of the 1,350-kv-a. 44,000-volt transformers failed
in service on July 7. Tests and inspection showed that one of the high-tension
coils in one phase had failed, and the complete section of winding was returned
to the manufacturer for repairs. Following repairs this transformer was again
placed in service on August 28. All the high-tension oil-breakers were overhauled.
A defective 44,000-volt bushing was replaced on one of the station service
transformers.
At Ranney Falls, plant No. C-10, the forebay was unwatered and the racks
were cleaned. The governors were overhauled and painted. A new 58-volt
storage battery was installed, replacing the defective battery used in connection
with the supervisory remote control equipment. Current transformers were
installed in the neutrals of each of the 4,500-kv-a. generators for protective
purposes. The high-tension oil-breakers were overhauled. All connections to
the 6,600-volt buses were overhauled. The generator room floor, steel window
sash and the low-tension gallery floors were painted.
At Seymour, plant No. C-ll, the forebay was unwatered and the racks
were cleaned. The exciter turbine and two of the main turbines were overhauled.
On one of the turbines the crown gear, countershaft and bearings had to be
replaced. All the governors were overhauled. The high-tension oil-breakers and
electrolytic lightning arresters were overhauled. The armature of the turbine
exciter failed in service and was returned to the manufacturer where it was
rewound. Disconnecting switches were installed on the bus side of two of the
low-tension feeder oil-breakers.
♦
At Heely Falls, plant No. C-14, the turbines were unwatered and inspected
but no extensive maintenance work was found necessary. The glands on each
turbine were repacked. The screen on the Pelton wheel of one unit was cleaned
and the debris was removed from the pit of another unit. The racks in front
of the penstocks were cleaned. Three new 44,000-volt side-opening disconnecting
switches were installed on one of the main transformer banks. The high-tension
and low-tension oil-breakers and lightning arresters were overhauled. Extensive
painting was carried out on the floors, walls, ceilings and steel window sash in
the control room, in the low-tension galleries and on the low-tension cell structures.
At Auburn, plant No. C-18, the forebay was unwatered and the racks were
cleaned. The walls of the forebay were inspected. One turbine was overhauled.
All the coils in each generator were examined and tightened, and all generators
were thoroughly cleaned and painted. The low-tension electrolytic lightning
arresters were overhauled.
42 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
At Fenelon Falls, plant No. C-30, the turbines were unwatered and com-
pletely overhauled. On one turbine a new set of 24 gate connecting rods was
made up and installed. New pins were installed in the regulating ring. The
gate stem shaft bearings were bored out and bushed, and a new gate stem shaft
was installed. On the second turbine 24 new gate bolts were installed in the
regulating ring and all the worn holes in the gate arms were welded. One of
the 400-kv-a. generators failed in service under normal operating conditions on
September 9. Approximately 60 coils were completely destroyed, 100 coils
were damaged and a section of the lamination which forms the coil slots was
badly burned. This generator has been in service for more than thirty years,
and the cause of the failure was undoubtedly due to deterioration of the insulation
on the bars. This machine will be completely rebuilt following reinsulation of
all the coils by the Commission's Service Department. A broken section of the
power house wall on the side next to the river was torn out and rebuilt.
At High Falls generating station on the Mississippi river the gate operating
mechanism of one turbine was completely overhauled. Due to some obstruction
the gate spindle in the gate house was bent when lowering the gate, but satis-
factory repairs were made by the Commission's maintenance staff.
At Calabogie generating station on the Madawaska river one of the main
turbines and the exciter turbine were unwatered and inspected but no extensive
maintenance work was found necessary. The 33, 000-volt and 6,600-volt electro-
lytic lightning arresters were completely overhauled. All interior and exterior
woodwork was painted. The lower layer of brick along the tail race wall was
renewed up to the sills of the lower windows.
At Galetta generating station on the Mississippi river, one turbine was
unwatered for the purpose of making minor repairs and adjustments. The
11, 000-volt electrolytic lightning arresters were overhauled.
Municipal, Distributing and Switching Stations
At Auburn transformer station the high-tension oil-breakers and electrolytic
lightning arresters were overhauled. One defective 44, 000-volt oil-breaker
bushing was replaced.
At Belleville switching station all the high-tension oil-breakers were
overhauled. New fences were built enclosing the station property and the switch
structures. The station site was greatly improved by grading.
At Belleville distributing station No. 1, a chain link fence was built partially
enclosing the station property. The station site was improved by grading.
At Colborne distributing station new insulators were installed on the
44, 000-volt lightning arrester horn gaps and new conductor was installed between
the horn gaps and the 44, 000-volt inlet bushings. A defective low-tension lightning
arrester was replaced on the Colborne feeder.
1934
HYDRO-ELECTRIC POWER COMMISSION
43
HORSEPOWER
HORSEPOWER
40.000
30.000
20.000
10.000
j8insgSS§i8g6iniis5§i8llgilIgi§S5ig|isllliiiS5§gi5lSlii§65i8
i i i i i i i 1 1 i i i i i i i i
EASTERN ONTARIO SYSTEM
OTTAWA DISTRICT
PEAK LOADS
HYDRO ELECTRIC POWER COMMISSION
OF ONTARIO
isiIIiilS§§g|l5iiIill5§i8isiilSiiS§iSisiilSil5§IgssilIiil6§i8
40.000
30.000
20.000
10.000
At Cobourg distributing station the high-tension and low-tension oil-
breakers were overhauled. A new 24-volt storage battery with trickle charger
was installed to supply tripping potential for the high-tension and low-tension
oil-breakers. A new gravity balance graphic wattmeter was installed to record
the load of Cobourg and the existing solenoid type graphic wattmeter was
reconnected with the necessary r-kv-a. resistances for recording the r-kv-a.
load. Individual phase ammeters were installed on all the low-tension feeders
and on the two transformer panels. All the electrical equipment was phase
44
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
Renfrew cist srsTEAf
33,000 V
S400
HORSfPOWSR
D
-#• RENFREW R>P D
RENFREW
33, OOP V
A 'RN PRIOR RURRL SYSTEM
—+- 3RRES/OE
ARN PRIOR
galctta
33,OOOK
CRATS FALLS
■^-CONSTRUCTION
STATION.
(DISMANTLED)
a
CRLRBOGiE DIST. SYSTEM
1070
HOffSEPOWEI
T
KINGDOM MINE
RR'K/P'/P/OR *>.*£>.
LEG EN'D
□
GENERATJNG STATIONS
("HORSEPOWER" 15 RATED ELECTRICAL
HORSEPOWER AT RATED POWER FACTOR)
TRANSFORMER STAF/OAAS
D/5TRI3L>rt/VC: STATIONS
STATIO/VS AND L/AIES //V SERVICf
STATIOAIS AND ll/VES IVOT COMMISSIONS PROPFRry
EASTERN ONTARIO SYSTEM
MADAWASKA DISTRICT
(60 CYCLES)
DIAGRAM OF STATIONS
AS AT OCTOBER 3!. 1933
marked and the low-tension transformer connections were rearranged so as to
make them standard phasing. The switchboard was rewired. The ceiling, floors,
and steel window sash were painted.
At Kingston switching station the high-tension oil-breakers were overhauled
on two occasions.
At Kingston distributing station the 750-kv-a. transformer was replaced by
a 1,500-kv-a. transformer, increasing the capacity of this station to 4,500-kv-a.
The high-tension oil-breaker was overhauled and painted. Insulating couplings
were installed in the transfer device of the 44,000-volt electrolytic lightning
arresters. A new ground conductor was installed between the high-tension
lightning arresters and the water main.
At Madoc distributing station the high-tension and low-tension oil-breakers
and the 44,000-volt electrolytic lightning arresters were overhauled. Two
defective 5 kw. bucking transformers were replaced on one of the low-tension
feeders. A chain link fence was built enclosing the substation.
At Maxville a new 44,000-volt 225-kv-a. distributing station was constructed
and placed in service on November 20, 1932. Previous to this date Maxville
and the Maxville rural power district obtained power at 4,000 volts from the
150-kv-a. transformer at Apple Hill.
FALLS \hORS£PO"£*\
„™TTT
"pi ! * m K.KD°
L r 7 ^"
KEMPTYILLE R R D.
°n°
CAMPdELLFVRO
-D D
r~^
1934 HYDRO-ELECTRIC POWER COMMISSION 45
At Oshawa No. 1 distributing station the high-tension oil-breakers were
overhauled on two occasions. The low-tension oil-breakers were overhauled
once. All electrical equipment was phase marked. The station site was improved
by grading and filling in the low areas at the back of the property. The station
floors were all painted.
At Oshawa condenser station the bearings of the 5,000-kv-a. condenser
were inspected and cleaned. The collector rings were ground and polished. The
starting switch of the 75-h.p. motor was overhauled. A new endless belt was
installed on the exciter of the 1,000-h.p. condenser. The steelwork, crane and
floors were painted.
At Ottawa 110,000-volt transformer station a defective bushing was replaced
on one of the 110,000-volt oil-breakers. Defective supports were replaced on
the 110,000-volt bus structure. A graphic instrument was installed at this
station whereby a remote record is obtained of the total power supplied to the
Commission by the Gatineau Power Company under the 60-cycle contract.
The instrument transformers, thermal converters, etc., used in connection with
this metering equipment, are installed at the Gatineau Power Company's
terminal station at Valtetreau.
At Picton distributing station defective insulators and pins were replaced
on the 44,000-volt bus. The 44,000-volt air-break switch was overhauled. The
transformers were inspected and painted. A coat of roofing compound was
applied to the station roof. The property fence was painted.
At Port Hope switching station all the high-tension oil-breakers were over-
hauled on two occasions.
At Port Hope distributing station the high-tension and low-tension oil-
breakers were overhauled. Defective lightning arresters were replaced on two
of the low-tension feeders.
At Sidney terminal station the high-tension oil-breakers and high-tension
electrolytic lightning arresters were completely overhauled. All the old pin-type
insulators were replaced on the outdoor high-tension structures. The old station
roofing was completely removed and replaced by three layers of three-ply felt,
each layer being rolled in hot asphalt. A coat of roofing compound was applied
to the roof of the lightning arrester annex. The station floors were painted.
At Smiths Falls transformer station the two 1,250-kv-a. single-phase trans-
formers and the 1,500-kv-a. three-phase transformer which failed in service on
August 27, 1932, were repaired and again placed in service on November 6, 1932.
The tap leads on the remaining two 1,250-kv-a. transformers were reinsulated
to prevent the possibility of similar trouble damaging these transformers.
At Williamsburg distributing station a second 100-kv-a. 44,000-volt single-
phase transformer was installed and placed in service on March 15.
At Wellington distributing station the 44,000-volt air-break switch was
overhauled. The 300-kv-a. transformer was thoroughly cleaned and painted.
The station floor and the property fence posts were painted. A coat of roofing
compound was applied to the station roof.
46
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
High-Voltage Transmission Lines
Work in connection with the inspection and maintenance of high-voltage
transmission lines was actively carried out during the year. Approximately
38,000 pin-type insulators were inspected, and 1,400 were found defective and
replaced. Approximately 10,000 poles were examined, of which over 900 were
found defective at the ground line and were stubbed. A considerable number of
poles were straightened and reset. Defective crossarms and timbers were replaced
where necessary. Approximately 8,800 poles were treated with a chemical pre-
servative. The usual programme of tree trimming and weed cutting was carried
out on various high-tension line sections. Defective power and telephone
conductors were replaced where necessary. A number of highway, railway and
foreign wire crossings were rebuilt to conform with present-day requirements.
Approximately 600 feet of defective twenty-pair telephone cable was replaced
between plants No. C-9 and No. C-10. This cable is used in connection with
the operation of the supervisory remote-controlled plants No. C-8 and No. C-9
which are controlled from plant No. C-10, Ranney Falls, near Campbellford.
Meter Department and Repair Shops
The usual programme of routine work in connection with the maintenance
of metering and relay equipment was carried out by the Meter department.
A series of special ground resistance tests were made at a number of stations
with a view to improving the high-tension neutral and high-tension arrester
grounds. Tests were also made on several of the station low-tension metering
grounds, and on station fences, etc., with a view to removing any possible hazard
due to potential gradients. Improvements were made at a number of stations
through the co-ordination of the high-tension and low-tension fuses. Phase
marking of high-tension lines and equipment was carried out at a number of
stations.
This department is available on request to any of the municipalities in
connection with the investigation of technical problems in the field.
The Belleville machine and meter repair shop has continued the usual
programme of testing and repairing the various types of service meters for
municipal and rural systems. A certain amount of work was also carried out in
connection with repairs and replacement parts for hydraulic and electric
apparatus.
EASTERN ONTARIO SYSTEM— LOADS OF MUNICIPALITIES— 1931-1932-1933
Municipality
Peak load in horsepower
Change in load
1932-1933
Oct. 1931
Oct. 1932
Oct. 1933
Decrease
Increase
Alexandria
184.5
28.0
74.2
212.9
30.1
82.4
23.4
3,701.4
227.7
32.4
74.4
29.2
3,786.6
14.8
Apple Hill.
2.3
Athens
8.0
Bath
5.8
Belleville
3,687.5
85.2
1934
HYDRO-ELECTRIC POWER COMMISSION
47
EASTERN ONTARIO SYSTEM— LOADS OF MUNICIPALITIES— 1931-1932-1933
— Continued
Municipality
Peak load in horsepower
Oct. 1931 Oct. 1932 Oct. 1933
Change in load
1932-1933
Decrease Increase
Bloomfield . .
Bowmanville
Brighton ....
Brockville. . .
Cardinal. . . .
Carleton Place
Chesterville . . .
Cobourg
Colborne
Deseronto
Finch
Hastings. . .
Havelock . .
Kemptville
Kingston . . .
Lakefield .
Lanark. .
Lancaster
Lindsay. .
Madoc. . .
Marmora . .
Martintown
Maxville. . .
Millbrook. .
Napanee
Newburgh . . .
Newcastle. . . .
Norwood
Omemee
Orono
Oshawa
Ottawa
Perth
Peterborough
Picton
Port Hope. . .
Prescott
Richmond. . . .
Russell
Smiths Falls. .
Stirling
Trenton
Tweed
Warkworth. . .
Wellington . . .
West port
Whitby
Williamsburg.
Winchester . .
87.8
1,551.4
284.8
2,271.2
131.3
848.5
197.7
1,468.6
182.3
146.8
38.9
73.7
227.9
241.9
4,580.0
227.7
61.8
62 9
1,718.9
165.7
89.2
26.1
72.6
68.9
1,015.2
41.0
82.5
135.3
76 6
58.5
7,369.9
24,841.8
1,069.1
6,158.4
887.4
1,108.0
815.5
39.4
57.9
1,597.9
265.1
2,874.1
189 9
75.8
205.9
1,028.5
69.7
216.4
73.4
1,546.2
270.7
2,380.1
139.7
966.5
191.1
1,424.7
163 6
148.6
42.3
65.2
175.6
241.3
5,105.2
209.7
64.7
33.6
1,564.5
153.6
85.8
21.5
80.4
79.6
935.2
42.6
64.2
116.3
77.4
78.3
6,494.6
5,758.6
1,038.9
6,011 4
871.6
1,081.9
770.8
45.9
42.6
1,509.3
239.9
2,745.4
169.2
67.7
191.7
65.1
1,009.4
142.1
235.7
76.1
1,528.8
279.9
2,329 1
142.3
1,030.8
159.9
1,501 3
126.8
118.5
44.9
73.9
131.3
246.2
5,429.6
223.8
71.8
43.8
1,760.1
152.1
84.7
21.8
85.2
75.6
978.7
45.6
101.0
96.1
97.7
78.6
6,722.5
26,208.0
1,135.4
6,407.7
869.8
1,149.1
696.5
47.4
51.1
1,468.4
213.1
2,911.1
145.9
73.4
167.5
69.4
987.9
198.4
231.5
17.4
5L0
31.2
36.8
30.1
44.3
1.5
1.1
4.0
20.2
1.8
74'3
40'9
26.8
23 . 3 '
24.2
21.5
4*2
2
7
9
2
2
64
6
3
76
6
2
8
6
7
4.9
324.4
14.1
7.1
10.2
195.6
0.3
4.8
43.5
3.0
36.8
20.3'
0.3
227.9
449.4
96.5
396.3
67.2
L5
8.5
165.7
"5.7
4.3
56.3
48
TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
EASTERN ONTARIO SYSTEM— RURAL POWER DISTRICT LOADS, 1931-1932-1933
Rural power district
Peak 1
oad in horsepower
Change
1932-
in load
1933
Oct. 1931
Oct. 1932
Oct. 1933
Decrease
Increase
Alexandria
25.0
281.6
160.4
16.8
269.0
58.9
184.5
220.3
77.0
20.0
415.5
13.4
265.7
10.0
4.0
62.5
118.4
31.9
145.8
563.8
61.7
21.0
3.0
667.1
3.0
476.4
92.0
46.2
211.0
139.0
3.0
169.7
32.8
30.4
304.0
97.3
22.8
288.1
67.3
186.2
242.9
94.2
47.2
445.0
18.1
296.2
32.7
10.0
53.4
156.0
34.3
177.2
624.3
72.6
27.9
3.0
677.0
21.4
420.4
109.8
48.1
151 8
127.5
3.0
194 6
52.8
31.5
324.8
106.4
22.8
298.2
69.5
184.3
270.7
120.0
52.5
428.1
19.3
323.7
34.3
16.4
47.4
156.6
36.3
213.9
590.6
63.6
22.9
2.0
626.2
34.8
391.1
106.4
46.2
183.7
204.7
3.0
175.6
73.3
1 1
Belleville
20 8
Bowmanville
9 1
Brighton
Brockville
10 1
Campbellford
2 2
Chesterville
1.9
Cobourg
27 8
Colborne
25 8
Fenelon Falls
5 3
Iroquois
16 9
Kemptville
1 2
Kingston
27.5
Lakefield
1 6
Lindsay
6 4
Mart in town
6.0
6
Millbrook
2.0
Napanee
36.7
Nepean
33.7
9.0
5.0
1.0
50.8
Newcastle
Omemee
Oshawa
Perth
13.4
Peterborough
29.3
3.4
1.9
Stirling
31.9
Trenton
77.2
Warkworth
Wellington
19.0
Williamsburg
20.5
THUNDER BAY SYSTEM
The load on the Thunder Bay System during the past fiscal year has shown
a slight increase over that of the previous year. A large amount of power has
been sold for the generation of steam electrically with the result that the average
monthly energy generated showed an increase of 16.1 per cent and the average
monthly peak an increase of 11.8 per cent over 1932. Excluding this steam
load, the average monthly energy generated was 5.9 per cent greater and the
average monthly peak 1.8 per cent higher in 1933 than in 1932.
The Nipigon Corporation Pulp Mill at Nipigon has not been operating
during the year, but the station has been maintained alive, Nipigon township
being supplied from this point.
934
HYDRO-ELECTRIC POWER COMMISSION
49
HORSEPOWER
JAN
FEB
MAR
APR
MAY
JUNE
AUG
SEPT
OCT
NOV
DEC
FEB
MAR
APR
MAY
JUNE
AUG
SEPT
OCT
NOV
DEC
JAN
FEB
MAR
APR
MAY
JUNE
JULY
SEPT
OCT
NOV
DEC
JAN
FEB
MAR
APR
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
JAN
FEB
MAR
APR
MAY
JUNE
JULY
AUG
SEPT
OCT
NOV
OEC
'^■ UUU ' M | II II | M 1 II 1 1 1 I 1 1 II II M II
THUNDER BAY SYSTEM
PEAK LOADS
HYDRO-ELECTRIC POWER COMMISSION
1Z!j,UU0 "~ " — -,,-.-. ^.- . . . ._ _|_
::::::::::::::::::::::::::::::::::[t::::::::::::::::::::::::
:::::::::::::::::::::::::::::::::t:::::::::::::::::::::::::
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10^? /
<J 2 . i /___ a V f\
____ 1931 „_„__ LS\ t-Xi-\-i- \-t
r-t~*\ i / A | \*' 1QOQ j iQ^n
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"*"______] n Z__;_:.<__,___,__:__I,___ J.
x ylJI -s:!--...^-:: *____«___/__
ixX 1927 1928- -A--- -----
j pr iy-w iy_io / r
1 Q9f; f 1 Q?c;
i y__D * , r i y__D
-i 1QO/I
«-* iy__.4
^"> >^^~^ ir_o?
4-4*ttT ^**-«--^r 1 ] 1 r 1923
1 __*_>. 1QOO Mill
lyzi iyzz
Mill Mill Mill
7.771
FLS
Mir,
MAi
JUNE
JULY
AUO
■>LPT
OC T
NOV
DE<
JAN
FEB
APR
MAY
JUNE
JULY
ALII,
OCT
NOV
DEC
J AN
FEB
MAR
APR
MAY
JUNE
AUQ
SEPT
OCT
NOV
OEC
JAN
FEB
MAR
APR
MAY
JUNE
JULY
AUO
SEPT
OCT
NOV
D£(
FEB
MAR
APR
JUNE
JULY
ALU,
SEPT
OCT
NOV
DEI.
HORSEPOWER
150,000
125,000
100,000
75,000
50.000
25.000
Two new loads have been added to the system during the year. A bank
of three 400 kv-a. transformers was placed in service at Cameron Falls generating
station in September, supplying power to Northern Empire Mines at Empire,
Ontario, over its 33, 000-volt transmission line. On October 2, two 8,000-kw.
electric steam-generators and auxiliary equipment at the Great Lakes Paper
Company were placed in service. Power is supplied to this steam station over
a short section of 110, 000-volt line, which is tapped off the line to the main
substation of this company.
Hydraulic maintenance work has been carried on at Cameron Falls generating
station during the year, the major items being the repairing of the eroded areas
of No. 3 and No. 6 turbines by welding the runners. As in former years, special
attention has been given to the testing and adjustment of governors. During
September a rather extensive programme of repairs to retaining walls and other
concrete structures was begun. This work, however, is only about 20 per cent
complete at the year end. The auxiliary hydraulic equipment has been maintained
in first class condition.
50 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
No major maintenance work has been carried out on any of the generators
at Cameron Falls generating station during the year. All power transformers
at this station have operated satisfactorily, routine maintenance work only
being required. The spare transformer, however, was completely overhauled.
Alexander generating station has given very satisfactory operating service,
no major maintenance work being required on any equipment throughout the
year. This station is supervisory controlled from Cameron Falls generating
station. A few troubles have been experienced with this control equipment, but
on the whole it has operated satisfactorily. The automatic synchronizer, which
is used in connection with this supervisory control, has given excellent service
throughout the year.
The service obtained from the transmission lines during the year has been
very good. There have been no total system interruptions, although Port Arthur
Fort William, Great Lakes Paper Co., and Thunder Bay Paper Co., were inter-
rupted for 2J/2 minutes on one occasion when No. 2 and 3 lines tripped out at
both ends and No. 1 line tripped out at Port Arthur during an electrical storm,
leaving No. 1 line alive to feed Nipigon Corporation. In addition to this, Great
Lakes Paper Co. suffered four interruptions of short duration, two due to
accidental operation of oil-breaker 2P1G during wiring alterations for new relays
at Port Arthur transformer station, and two due to flashovers during electrical
storms. Fort William experienced one two-minute interruption when a bird
caused a transmission line flashover. Flashovers during electrical storms were
responsible for two interruptions, one of 21 minutes and the other of 7 minutes
duration, to Nipigon Corporation station. The service to Northern Empire
Mines was interrupted on two occasions due to trees falling across the line.
Special attention has been given to testing the line insulators and replacing
those found faulty. Also, the line conductors were closely inspected for broken
or loose strands and these were repaired where necessary. Some other mainten-
ance work has been done on the wood-pole lines in tightening guys, etc. Brush
was cut along certain sections of the right-of way.
The Port Arthur transformer station has had no curtailment of service to
any customers due to failures of equipment. New relay equipment was placed
in service on all 110,000-volt lines, both incoming and outgoing, at this station.
While sufficient time has not yet elapsed to make a definite statement regarding
the improvement to service, the time of operation of the breaker equipment
has been materially reduced, resulting in faster clearances of faults and hence
less disturbance to the system. Routine inspection and maintenance of the
110,000-volt oil-breakers and transformers has been carried on throughout the
year. Connections to the three 110,000-volt lines were altered so that two or
three lines could be fed through one oil-breaker, thus enabling the other oil-
breakers to be taken out of service for maintenance purposes.
The Fort William transformer station has had no failure of equipment or
incorrect functioning of relays or breakers. Routine maintenance work only
was required at this station.
The precipitation in the watershed supplying this system has been relatively
heavy during the year, approximately 28 inches being recorded. With the light
1934
HYDRO-ELECTRIC POWER COMMISSION
51
GREAT LAKES
PAPER CO. LTD.
(FORT WILLIAM)
(— I
■FORT WILLIAM FORT WILLIAM
'"-^ 22,000 V. f- 1
tP"
I/O.000 V.
//0,000 V.
THUNDER BAVr-i //0, OOQV .
PAPER CO. L.J
PORT ARTHUR
\m™™ « „ OmO0OV
NORTHERN
EMPIRE
M/HESCO.ITO.
< 1
Q
il
CAMERON FALLS \n
_ 22,000 V.
111
22,000 V.
%*?m r^V?™
68,200
HORSEPOWER
ALEXANDER
5/, 300
HORSEPOWER
PORT ARTHUR
2,300 V .
PORT RRTHU/f **D- 0>MT) /yiPIOON
pumping station corporation l to.
PORT ARTHUR R.PD. rPART)
LEGEND
GENERATING STATIONS
("HORSEPOWER' IS RATED ELECTRICAL
HORSEPOWER. AT RATED POWER FACTOR)
TRANSFORMER STATIONS
] DISTRIBUTING STATIONS
O
THUNDER BAY SYSTEM
(60 CYCLES)
DIAGRAM OF STATIONS
AS AT OCTOBER 31. 1933
MUNICIPAL STATIONS
STATIONS & LINES IN SERVICE
STATIONS & LINES NOT COMMISSIONS PROPERTY.
HYORO'ELECTRIC POWER COMMISSION
OF ONTARIO
load on the system and the heavy precipitation it was found necessary to waste
a considerable amount of water at both plants during the greater part of the
year. Notwithstanding the high river flow, the level of lake Nipigon has been
raised about 6 inches during the year.
THUNDER BAY SYSTEM— LOADS OF MUNICIPALITIES, 1931-1932-1933
Municipality
Peak load in horsepower
Change
1932
in load
■1933
Oct. 1931
Oct. 1932
Oct. 1933
Decrease
Increase
Fort William
11,451.7
70.3
27,024.4
10,916.7
83.0
35,195.1
10,932.0
101.1
33,205.5
15.3
Nipigon Township
Port Arthur
' 1,989.6
18.1
THUNDER BAY SYSTEM— LOADS OF RURAL POWER DISTRICTS
Rural power district
Peak load in horsepower
Oct. 1931
Oct. 1932
Oct. 1933
Change in load
1932-1933
Increase
Fort William
35.0
23.7
80.0
33.2
45.0
Port Arthur
9.5
52
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
HORSEPOWER
HORSEPOWER
cnnn < g 1 a 1 I * g a 8 g a I g I a I % i 1 1 8 i a I g I %l 1 1 1 y | a I g I j 1 1 g j g 8 i 1 1 B jj 1 1 g g as i s .,
5,000 i j | | I I | I I | i i i i i i i i i ] i i i i i i i i i i i i ' i i i i i i i i i i i i i i i i I I I I I j.UUu
4.000
3.000
2.000
1,000
S3S33=38S2S
NORTHERN ONTARIO PROPERTIES
NIPISSING DISTRICT
P EAK LOAD S
HYDRO-ELECTRIC POWER COMMISSION
OF ONTARIO
§ 3 S 3 o o BIS S S S S § a S a 5 o Bl< S S E S § a = a « o u
iSliliiiigii
4,000
3,000
2,000
1,000
NORTHERN ONTARIO PROPERTIES
Nipissing District
Although the generated peak and average loads on the Nipissing district
show slight increases for some months over the corresponding months of the
previous year, a small decrease in load is shown when the records for the entire
year are compared with those of the previous year.
The greater storage facilities provided during recent years permitted the
retention in storage of more water during the spring flood period than in previous
years, with the result that river flow has been satisfactorily maintained despite
an unusually dry summer.
The chief item in the line maintenance programme for the year was the
replacement of all defective poles, crossarms, insulators and insulator pins on
the Callander to North Bay, Bingham Chute junction to Callander, and Elliott
Chute junction to Bingham chute junction sections. All line crossings over rail-
ways or foreign wires which were found to be substandard, were brought up
to the standards required by the Board of Railway Commissioners.
1934
HYDRO-ELECTRIC POWER COMMISSION
53
HOW FY GOLD MINES LTD.
PATRICIA DISTRICT
ABITIBI CANYON
55,000
HORSEPOWER
EAR FALLS
/HTERHATIONAL NICKEL CO.
AT COPPER CLIFF
5,400
HORSEPOWER
.i l
no. ooov.
1 j
ABITIBI DISTRICT'S cycles)
n
■OJ
TREAD WELL
YUKON MINES
3.
5.IOO
\ horsepower
Z 2.000 V.
(N0.2)MCVITTIE
BUR WASH ^,
FARM 2,300 V.
E, 680
HORSEPOWER
2 2.000 V.
(NOJ)CONISTON
FAL CON BRIDGE
NICKEL CO.
5,360
HORSEPOWER
(HO. 3) STINSON
SUDBURY DISTRICT
MANITOULIN R.P.O..
II
~| HAGA WONG
r
i i
LITTLE RAPIDS PULP COMPANY
MANITOULIN DISTRICT
L
HORTH BAY R.PD.
ABIT/BI POWER <J PAPER CO.
STURGEON FALLS
HORTH BAY I I
NO. 2 LJ
2 2, OOOV.
□ NORTH L
NO. I
7}
CALLANDER I I
(CANADIAN TIMBER CO. LTD} I
2.750
HORSEPOWER
BIHGHAM CHUTE
/.200
HORSEPOWER
ELLIOTT CHUTE
1,930
HORSEPOWER
-o
I-*- POWASSAN 1
POWASSAN RPD '
NIPISSING DISTRICT
LEGEND
GENERATING STATIONS
(HORSEPOWER" IS RATED ELECTRICAL
HORSEPOWER AT RATED POWER FACTOR)
~J DI5TRIBUT/HG 5TATIOHS
O MUNICIPAL STATIONS
— STATIONS £ LINES IN SERV/CE
_ STATIONS « LINES NOT
COMMISSION'S PROPERTY
NORTHERN ONTARIO PROPERTIES
(60 CYCLES) — (25 CYCLES)
DIAGRAM OF STATIONS
AS AT OCTOBER 31. 1933
HYDRO-ELECTRIC POWER COMMISSION
OF ONTARIO
54 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
At Nipissing generating station, new Niagara bronze runners were installed
in each of the two turbines to replace the cast iron runners which had eroded
to an extent that made economical repairs impossible. Minor repairs and adjust-
ments to both turbines were also undertaken. Considerable painting was done
on buildings and equipment as a protective measure. The design of the pistons
in the governor oil pumps was changed to eliminate the oil leakage permitted
by the old design.
A number of leaks in the wood-stave pipe line were stopped by covering
each leak with a layer of tarred felt held in place by a steel plate pre-formed
to the curvature of the pipe and inserted under the pipe bands. Several of the
pipe line supporting saddles were also renewed.
At Bingham Chute generating station, very little maintenance work was
found necessary on the turbines. Renewal of gate link pins on No. 2 unit,
renewal of lignum vitae bearings and adjustment of journal bearings on both
units were undertaken. One 300-kw. power transformer at this station failed
in service due to development of a leak in the bronze cooling coils. Repairs
were made to the winding, the defective coils were replaced with new copper
coils, and the old oil, which was known to be slightly high in acid content, was
replaced with new oil. Renewal of coils and oil in the remaining two transformers
in the three-phase bank is being undertaken to safeguard against similar failures
in these units. The choke coils were removed from the 22,000-volt structure.
Earth resistances were measured and station grounding improved.
The chief operator's cottage at this station was completely redecorated.
At Elliott Chute generating station, only routine turbine maintenance work
was required. A new spring type flexible drive for the generator overspeed
device was installed to replace the original drive which has failed on several
occasions.
A woven wire fence was erected along the roadway on the southern boundary
of the property.
The decayed plank facing of the rock-filled woodcrib breakwater at this
station was renewed with 1-inch plank and covered with one-eighth-inch steel
plates from salvage. The frame store-house was raised and placed on concrete
posts. The west end of the earth fill dam was surfaced with 30 yards of gravel.
At the Canadian Timber Company substation in Callander, one high-tension
transformer bushing failed in service and was replaced with a new bushing.
Megger tests on practically all electrical equipment were made throughout
the year, initiating a programme of periodical megger tests to obtain indications
of insulation deterioration by comparison of results of tests taken at intervals
over a period of time. The programme of progressive grading of insulators,
instituted last year, was continued through the current year.
1934
HYDRO-ELECTRIC POWER COMMISSION
55
20,000
10,000
FEB
MAR
APR
MAY
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
JAN
FEB
MAR
APR
MAY
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
JAN
FEB
MAR
APR
MAY
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
JAN
FEB
MAR
APR
MAY
JUNE
AUG
SEPT
OCT
NOV
DEC
JAN
FEB
MAR
APR
MAY
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
T
i o^n 1 qiq -
(you iyo«3
1931
'V -> f*y '^ w " icn? /^
* lA -, r J
::::::::::„:_^:"/::^,::::::::"::::t::::::::::::::::i
____L---_w-- y ---,J
XJ—
*j j
m
NORTHERN ONTARIO PROPERTIES
SUDBURY DISTRICT
DC" A V 1 HA nC
rtAr\ LUAUo
HYDRO -ELECTRIC POWER COMMISSION
1 1 1 1 1 1 II 1 1 1 1 1 1 1 1 1 1 II II ! 1 II 1 I 1 1 II II 1
jam
FEB
APR
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
FEB
MAR
APR
MAY
JUNE
AUG
SEPT
OCT
MOV
DEC
JAM
FEB
MAR
APR
MAY
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
JAM
FFB
MAR
APR
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
JAM
FEB
MAR
APR
MAY
JUNE
AUG
SEPT
OCT
NOV
DEI
20,000
10,000
Sudbury District
The generated peak and average loads on the Sudbury district showed a
marked decrease for the first six months of the current fiscal year as compared
to corresponding months of the previous year. Owing to improved conditions
in the nickel industry, however, a decided upward trend, which started in May,
1933, has continued throughout the remainder of the year. The extent of this
improvement is illustrated by the fact that in October, 1933, the generated
peak load showed an increase of 65 per cent and the generated average load an
increase of 91 per cent over the corresponding month of 1932.
The level of Wahnapitae lake was lowered approximately four feet below
the normal operating level during the summer months to accommodate certain
mining properties bordering on the lake. This action together with the
subnormal precipitation of the past summer demanded more than usual care in
the regulation of river flow and division of load between generating stations in
order to obtain the maximum efficiency in the use of storage water.
Line maintenance work in the district was confined to insulator testing,
replacement of defective insulators, butt treatment of poles where necessary and
similar details of a routine nature.
At Coniston generating station, No. 2 turbine was completely overhauled.
This work included the installation of alemite fittings to facilitate greasing of
bearing surfaces between gates and gate bolts and between speed rings and
operating rings. A new gear quadrant was installed on the gate operating
mechanism. New gate links, link pins, and link bushings were supplied where
required.
56 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
Four new timber head-gates were constructed and installed to replace the
head-gates which had become unsafe through deterioration of the timbers.
The generating station air compressor was moved to a new and more con-
venient situation. Repairs were made to the roofs of the store-house, generating
station, transformer house and penstock house. The generating station floor,
boarding-house interior woodwork and store-house and transformer house trim
were painted.
The road between the generating station and the highway was widened
and surfaced with gravel.
To improve frequency regulation and time service a synchronome, having
a synchronous motor driven clock and an accurate mechanical clock movement
with dials to indicate the variation between times as computed by the two
types, was installed at Coniston generating station. A radio receiving set for
the reception of time signals was also installed to permit accurate setting of the
mechanically operated movement. With the synchronome indication as a guide
the staff has been able to regulate system frequency much more closely than
heretofore.
At McVittie generating station, the armature of No. 1 generator failed in
service on four occasions and the armature of No. 2 generator failed once during
the year. Failures in all cases were due to lightning surges which are assumed
to have entered the station on a 2,200-volt feeder. These generators have been
in service for more than twenty years and the repeated failures were attributed
largely to deterioration of the windings with age. A complete new winding has
been installed in No. 1 generator to eliminate further costly failures.
Mechanical maintenance work at this station was confined to small items
such as the renewal of the lignum vitae bearing and the replacement of a defective
thrust nut on the exciter turbine, governor adjustments, and repairs to two
bearing pedestals in which cracks had developed. A set of disconnecting switches
was installed to permit isolation of the high-tension arresters. Station grounding
was improved and tested. Extensive painting inside the generating station was
undertaken.
At Stinson generating station, the two 3,500-horsepower turbines were
completely overhauled. Each unit was equipped with alemite fittings to facilitate
greasing the bearing surfaces between gates and gate bolts and between speed
rings and operating rings. A brake was installed on each unit whereby the unit
can be quickly stopped by application of pressure to the periphery of the flywheel.
Following the failure of one of the timber head-gates at this station, two
new head-gates of heavier design were installed to replace the originals. A pipe
railing was erected on the lower side of the path between generating station
and head block as a safety measure.
The exterior walls of the penstock building were painted and one coat of
roofing paint was applied to the roof. Rust was removed from the penstocks
and the cleaned surface painted, where required. Considerable painting was
undertaken inside the station.
1934
HYDRO-ELECTRIC POWER COMMISSION
57
HORSEPOWER
HORSEPOWER
60,000
>
JAN
FEB
MAR
APR
MAY
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
JAN
FEB
MAR
APR
MAY
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
JAN
FEB
MAR
APR
MAY
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
JAN
FEB
MAR
APR
MAY
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
FEB
MAR
APR
MAY
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
A
1
'
- 1Q^^ -
i yoj
- 1 QOI _ 1 QOO
lyoi lyjz
1 4
4X— JL ..--/--- —
k. j \„ -e' J ^
• nnwi — - — - _- MADTUTDM r\MTADir\ DDADCDTirC -
10,000- - -- -- -- inUKIHLKIN UlNIAKIU rKUrLKIItb
ABITIB1 DISTRICT
PEAK LOADS
HYDRO-ELECTRIC POWER COMMISSION
OF ONTARIO
r.
JAN
FEB
MAR
APR
MAY
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
JAN
FEB
MAR
APR
MAY
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
JAN
FEB
MAR
APR
MAY
JUNE
JULY
AUG
SEPT
OCT
NOV
OEC
JAN
FEB
MAR
APR
MAY
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
JAN
FEB
MAR
APR
MAY
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
50,000
40.000
30.000
20,000
10,000
Abitibi District
On the Abitibi district the peak and average loads for the first eight months
of the fiscal year were, in general, slightly higher than for the corresponding
months of the previous year. Improved conditions in the nickel industry were
responsible for a decided load increase during the next three months, and during
the final month of the fiscal year the load was greatly increased by the addition
of the Abitibi Power and Paper Company's steam-generation load at Iroquois
Falls.
Until the No. 1 unit at Abitibi Canyon generating station was first placed
in service, power was purchased from the Abitibi Electric Development Com-
pany's generating station at Island Falls for transmission to Copper Cliff to
serve the International Nickel Company at that point. This power was trans-
mitted from Island Falls to Hunta, 14 miles west of Cochrane, over the Abitibi
Electric Development Company's circuit and from Hunta to Copper Cliff, a
distance of 189 miles, over the Commission's double-circuit steel-tower line.
58 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
On May 24, the Copper Cliff load was transferred from Island Falls generating
station to the Abitibi Canyon generating station, thus marking the initial
delivery of commercial power from the latter station. A double-circuit steel-
tower line from Abitibi Canyon generating station is connected at Hunta to
the aforementioned double-circuit steel-tower line from Hunta to Copper Cliff,
making a total transmission distance from Abitibi Canyon to Copper Cliff of 246
miles. A single circuit only is used to supply Copper Cliff at the present time
but the second circuit is kept available for service as a standby.
On October 23, the initial delivery of power was made to the Iroquois
Falls mill of the Abitibi Power and Paper Company, for purposes of steam
generation. This power is transmitted over the Commission's lines from Abitibi
Canyon to Hunta where connection is made with the Abitibi Electric Develop-
ment Company's line to Iroquois Falls.
Service interruptions due to electrical storms have been more frequent on
this district than would be anticipated from the records of other districts operated
by the Commission. This has been attributed to the apparent higher storm
frequency in the area served, coupled with the fact that the 246 miles of trans-
mission line from Abitibi Canyon to Copper Cliff runs almost due south, thus
intercepting a greater number of storms (which usually travel east and west)
than the Commission's other lines of similar length which run in an east and
west direction.
Maintenance of lines on the district was confined chiefly to replacement of
a small number of insulators, most of which showed evidences of being damaged
by rifle shots. Considerable brush cutting was found necessary on the right-of-way
of the Hunta to Copper Cliff section of line. A close inspection of lines for loose
tower bolts, deterioration of absorber rods, power conductor and ground con-
ductor at points of suspension was made in both the spring and fall seasons.
The operation of the Abitibi Canyon generating station has been satisfactory
during the few months it has been in service. Various adjustments and changes
have been necessary, as is usually the case when a new station is placed in service,
but these have been of a minor nature.
Toward the latter part of August the second generator at Abitibi Canyon
generating station was sufficiently advanced to be placed in service. This released
No. 1 generator for various adjustments. From this time to the end of the fiscal
year, although two generators were at times available, the necessity of removing
one or the other from service for adjustment, limited the capacity available for
commercially continuous service to that of one unit.
Patricia District
The generating and transformer station at Ear Falls on the English river
has been in satisfactory operation throughout the year. All equipment has
functioned as required, there being no failures of major importance. The load
on the system has shown an increase over that existing during the previous year.
The average monthly energy generated was about 2.8 per cent greater and the
average monthly peak approximately 8.9 per cent higher during 1933 than
in 1932.
1934
HYDRO-ELECTRIC POWER COMMISSION
59
HORSEPOWER
HORSEPOWER
3.000
3
3
JAN
FEB
APR
MAY
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
FEB
MAR
APR
MAY
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
JAN
FEB
MAR
APR
MAY
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
JAN
FEB
MAR
APR
MAY
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
JAN
FEB
MAR
APR
MAY
JUNE
AUG
SEPT
OCT
NOV
DEC
J,uuu Mill
IQOQ
iyjo
f
1QQ9 J
i yo^i j
1 QOI 1 ' j
lyoi ^^-^ 7
Z.UUU f ' ^^?3 • ' V '" ~1~
1QOf| ~S
i yju *->
/*"**"*"
/r /
/ NORTHERN ONTARIO PROPERTIES
J PATRICIA DISTRICT
* " PEAK LOADS
HYDRO-ELECTRIC POWER COMMISSION
OF ONTARIO
c
JAN
FEB
MAR
APR
MAY
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
JAN
FEB
MAR
APR
MAY
JUNE
AUG
SEPT
OCT
NOV
DEC
FEB
MAR
APR
MAY
JUNE
AUG
SEPT
OCT
NOV
DEC
FEB
MAR
APR
JUNE
JULY
SEPT
OCT
NOV
DEC
JAN
FEB
APR
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
2,000
- 1,000
Four interruptions to service took place during the year, one of which was
of rather long duration. On November 16, 1932, oil breaker IB IT opened
automatically due to trouble on the 44,000-volt transmission line. The trouble
was found to be due to failure of a crossarm through-bolt which permitted the
arm to swing down against the telephone crossarm, breaking one insulator.
Due to communication being cut off from the Howey Mines and travelling in
the deep snow being very slow, service was not resumed until 31 hours and 6
minutes later. On June 29 a 2-minute interruption to service occurred due to
a flashover on the 44,000-volt transmission line during a lightning storm. On
July 24 service was interrupted for one minute when oil-breaker IB IT opened
automatically in conjunction with oil-breaker 151 on the feeder to the water
rheostat, due to a flashover on this feeder during a lightning storm. On August
16 a flashover occurred on one of the 2,200-volt feeders at Howey Mines during
a lightning storm, 1B1T oil-breaker opened automatically and the operator had
some difficulty in restoring normal voltage to the generator, with the result
that an interruption of 19 minutes resulted.
A certain amount of maintenance work has been carried out on the major
equipment during pre-arranged plant shut-downs. On July 7 the turbine was
unwatered and the turbine and various hydraulic features were inspected and
found to be in good condition. The turbine-operating mechanism, governor
system and auxiliary mechanical equipment have been inspected and overhauled
where needed.
The 44,000-volt transmission line between the generating station and the
Howey gold mine, which is owned by the Howey Gold Mines Limited, has been
operated and maintained for this Company throughout the year under the same
arrangement for costs as previously. This transmission circuit has functioned
very satisfactorily during the year, although it was responsible for the two
outages outlined above.
The flow in the English river has been adjusted from time to time, as required
by the Lake-of-the-Woods Control Board, by means of the regulating dam at
Ear Falls.
60
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
The precipitation in the vicinity of Ear Falls has been about normal, being
25 inches during the year. With this precipitation, as well as conservation of
water when not required, the level of Lac Seul has been raised about one foot
during the year, the elevation on October 31, 1933, being 1160.8 as against
1159.9 on the corresponding day last year.
Manitoulin District
The Manitoulin district was first served by the Commission on December
16, 1932. Power purchased and metered by the Commission at the 600-volt
bus of the Manitoulin Pulp Company's mill at Kagawong is stepped up to
12,000 volts between phases by means of three 100-kv-a. transformers which
are installed in an outdoor-type station close to the mill. From this station
power is supplied to the Manitoulin rural power district which at present consists
of the municipalities of Gore Bay, Mindemoya and Kagawong, and a number
of rural customers. Service has been satisfactorily maintained throughout the
year.
NORTHERN ONTARIO PROPERTIES— LOADS OF MUNICIPALITIES, 1931-1932-1933
Municipality
Peak load in horsepower
Oct. 1931 Oct. 1932 Oct. 1933
Change in load
1932-1933
Decrease Increase
NIPISSING DISTRICT
Callander. .
Nipissing. . .
North Bay
Powassan . .
112
8
3
2,921
8
117
7
175
3
,915
131
196
4
3
,911
4
106
5
3.6
24.5
21.4
SUDBURY DISTRICT
Sudbury
3,967.8
3,667.5
3,599 2
68.3
NORTHERN ONTARIO PROPERTIES— LOADS OF RURAL POWER DISTRICTS,
1931-1932-1933
Rural power district
Peak load in horsepower
Oct. 1931 Oct. 1932 Oct. 1933
Change in load
1932-1933
NIPISSING DISTRICT
North Bay
68.3
77.0
2.0
77.9
3.0
9
Powassan .
,0
MANITOULIN DISTRICT
Manitoulin ...
Date connected
Dec. 16/32
Initial load
70.0
79.9
9 9
1934 HYDRO-ELECTRIC POWER COMMISSION 61
SECTION III
MUNICIPAL WORK
The Commission acts in an advisory capacity in connection with the
operation of the "Hydro" utilities of the various municipalities with which it
has contracts. In this connection the Commission arranges for the purchase,
construction or extension of distribution systems and assists the municipal
officials in making their financial arrangements to pay for the cost of these
systems. All rate adjustments, as provided under The Power Commission Act,
are recommended by the Commission, and a study of the operating conditions
of all utilities is made annually and adjustments recommended accordingly.
The Commission exercises a general supervision over the management and
operation of all systems more especially in the smaller municipalities which,
individually, are not of sufficient size to employ a manager with the technical
knowledge necessary to administer properly all phases of the local system's
operation.
In the case of the rural power districts, the Commission itself — on behalf
of the corporations of the individual townships — operates the rural power
systems, and distributes electrical energy to the customers of the respective
corporations in any such rural power district.
NIAGARA SYSTEM
During the month of July, 1933, the Commission commenced taking power
from the McLaren-Quebec Power Company. This power was transmitted over
the 220,000-volt line from Beaudet to Chats Falls generating station by which
power is obtained from the Beauharnois Light, Heat and Power Company.
Commencing with the month of October, an additional block of power was
taken from the Beauharnois Light, Heat and Power Company also over this
line.
The load conditions on the Niagara system during the fiscal year, 1933,
show an increase in the total amount of power taken by municipalities and
industrial companies during the months of November and December, 1932,
February, April, July, August, September and October, 1933, as compared
62 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
with the corresponding months of the previous year. During the months of
January, March, May and June, a slight decrease is shown in the amount of
power taken, as compared with the previous year. These figures, however, do
not include secondary power sold for process steam generation, and for export
to the United States. Commencing with the month of February, the Com-
mission sold a substantial block of secondary power to the pulp and paper
industry for the generation of process steam, and in the month of June, resumed
the sale of additional secondary power to the Canadian Niagara Power Company
for export. The loads on the systems of the Commission are referred to more
fully in Section II of this report.
Dominion Power and Transmission Properties
The distribution systems of the Dominion Power and Transmission Company
in the cities of Hamilton and Brantford which were sold during 1931 and 1932
respectively have proved to be entirely satisfactory. The arrangements of sale
provided for the purchase of these properties by payments extending over a
number of years, but it is expected that the entire purchase price of the systems
in both these cities will be paid sooner than originally planned.
Negotiations are under way in connection with the sale of the Dominion
Power and Transmission Company's distribution system in St. Catharines to
the local commission. The rural distributing lines of this Company have already
been absorbed in the several rural power districts in which they are situated.
"Secondary" Power
"Secondary" power is a term applied to power which is sold subject to
unlimited interruptions, to reduction or to complete withdrawal, at any time
it is required for use by municipalities, or for the maintenance of the supply
of firm power. Although the Niagara system of the Commission has a high
load-factor it has, of course, daily and seasonal peaks; thus there are, even in
times of normal industrial activity, periods of the day and of the year when
large amounts of "secondary" power are available. "Secondary" power, how-
ever, on account of the uncertainty of the times and durations of the system
peaks, is not sufficiently dependable for ordinary industrial uses. A limited
amount of such power can be utilized by large special industries in certain
heating and electro-chemical processes. Although Canadian consumers are at
all times given priority of consideration, the chief market for "secondary"
power which the Commission has had at its disposal on the Niagara system has
up till recently been in adjacent territory in the United States served by supply
systems securing a large proportion of their power from steam plants. Such
systems, by utilizing, when available, this "secondary" power can conserve their
fuel supplies. The sale of this power to the Canadian Niagara Power Company
for use in the United States has enabled the Commission to employ profitably
its generating equipment at times when not required to take care of the demands
of the Niagara system. During the latter part of the year this Company has
resumed taking this kind of power in substantial quantities.
1934 HYDRO-ELECTRIC POWER COMMISSION 63
Profitable Employment of System Reserve Generating Capacity
In times of curtailed industrial activity the amount of reserve power capacity
which it is necessary to maintain, increases. If this reserve capacity can be
put to profitable temporary use under conditions or contracts that ensure the
maintenance of its character as system reserves, it is an economic gain to the
Province and brings to the Hydro undertaking a revenue which reduces the cost
of maintaining the essential reserves.
One market for this type of power is found in the production of steam for
industrial processes. During the past year the Commission has supplied sub-
stantial amounts of secondary power for steam purposes and arrangements are
being made to supply other companies in a similar manner. As general economic
conditions improve, there will be less reserve power available for this purpose
because more will be required for the normal uses of the municipalities. Mean-
time, it may be noted, the utilization of reserve power for the production of
process steam replaces imported coal.
Engineering Assistance to Municipalities
General engineering assistance was given during the year to practically all
of the municipalities in the Niagara system, by a general supervision of
management and operation.
Estimates and work in connection with the rebuilding of distribution systems
to take care of various conditions was undertaken during the year and additional
transformer capacity provided where necessary in the following places : Amherst-
burg, Aylmer, Beachville, Blenheim, Brampton, Caledonia, Dresden, Drumbo,
Dundas, Exeter, Fergus, Fonthill, Goderich, Mimico, New Hamburg, Niagara-
on-the-Lake, North YorkTwp., Otterville, Paris, Plattsville, Port Credit, Preston,
Ridgetown, St. Jacobs, Seaforth, Simcoe, Strathroy, Tilbury, Toronto Twp.,
Waterdown, Wellesley, Weston and Woodbridge.
Certain municipalities received special engineering advice and assistance
regarding a number of matters, which are more fully referred to as follows:
Chatham — A 200-horsepower fire pump is being installed. The motor will
operate at 4,000 volts and the pump will have a capacity of 5,000,000 imperial
gallons per 24 hours at a pressure of 110 pounds. The present steam pump
stand-by will be replaced with two gasoline-engine driven pumps in order to
reduce the waterworks operating costs. The distance from the Chatham Hydro
utility step-down station to the waterworks pumping station is approximately
one mile and a special feeder will be erected.
Dunnville — An additional primary circuit and a new transformer bank were
constructed for service to power consumers who were increasing their loads.
Georgetown — New lines were designed and their locations determined
preparatory to removing circuits from the main street. Arrangements were made
also for additional primary lines to improve service to power customers.
64 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
Goderich — Plans were made for rebuilding of a portion of the distribution
lines which had become overloaded and particularly with a view to securing a
primary loop so that interruptions for repair work would be reduced to the
minimum.
Humberstone — Provision for convenience of operation and better service
by arranging for interswitching with Port Colborne, is being undertaken, together
with general system revision. Plans were submitted by the Commission's
engineers and the work is being done under their supervision.
London — A new 13,200-volt feeder consisting of 3-conductor 4/0 cable was
laid between the Commission's high-tension station and the corner of Highbury
avenue and King street to take care of the increasing industrial load in this area.
St. Marys — The severe wind storm on June 9, badly damaged the circuits in
all parts of St. Marys. Advantage was taken of the situation when rebuilding to
replace equipment which had become inadequate, particularly conductor, and a
large portion of the distribution system was rebuilt with larger conductor, new
poles and heavier line material.
Sarnia — Specifications were prepared for the installation of two electrically
driven domestic water pumps in the waterworks plant. These pumps will be
equipped with 4, 000- volt motors and have a capacity of 150 and 200 horsepower
respectively. The present steam-driven pump will be retained as a stand-by in
case of fire. Power will be supplied over a separate feeder from No. 1 municipal
station to the pumping plant, a distance of approximately one and a half miles.
The pumps will be capable of delivering 3,240,000 imperial gallons and 4,320,000
imperial gallons of water per 24 hours.
Tillsonburg — Plans are being prepared for the complete overhauling of
the local substation, partly due to increased load and partly to obtain better
operating conditions.
GEORGIAN BAY SYSTEM
A small increase occurred in the power demand of this system during the
year, but for the most part, the loads in the various municipalities were constant
with respect to previous year conditions. A new industry of fair magnitude in
one of the municipalities, together with a large number of new consumers taken
on in the summer resort districts, established a higher system peak during a
portion of the year, but as the new summer load is in existence for only about
two or three months, and as the new industrial load was in operation during the
latter part of the year only, the total yearly average load increase was not greatly
affected.
The distribution system in the village of Mildmay purchased last year by
the Commission from The Mildmay Electric Light Company, was sold to the
corporation of the village, and the distribution system purchased last year from
1934 HYDRO-ELECTRIC POWER COMMISSION 65
The Formosa Electric Light Company was merged into the Bruce Rural Power
District, and service given to the various consumers in accordance with the rural
sections of the Power Commission Act.
A new 22,000-volt transmission line was constructed between Shelburne
and Orangeville replacing the old line purchased from The Pine River Light &
Power Company in 1916, and all financial matters, as well as all features of
improved service in connection therewith, were placed before all the munici-
palities affected by the change, and approval obtained. Arrangements were also
made for reconstructing the transmission line between Grand Valley and Arthur,
and a large portion of this was completed during the year.
General engineering assistance and advice concerning the maintenance and
operation of the various local distribution systems, also assistance in connection
with the application of rates, and the submission of information to power and
lighting customers was rendered to all of the municipalities throughout the year.
Engineering advice of a special nature in connection with matters referred
to was given to the following municipalities:
Chatsworth — Plans and specifications were prepared covering a complete
rebuilding of the local distribution system.
Formosa — The primary line out of the Walkerton generating station which
feeds the hamlet of Formosa, as well as the local distribution system of Walkerton,
was completely reconstructed and made a part of the Bruce rural power district.
Kincardine — The Public Utilities Commission submitted information con-
cerning the cost of power to a new industry. It negotiated a contract for power
service, rebuilt a portion of the distribution system in order to deliver power to
this new consumer, and enlarged the local substation to provide adequate trans-
former capacity for supplying this new load in conjunction with the existing load
in the municipality.
EASTERN ONTARIO SYSTEM
This system includes the Central Ontario, St. Lawrence, Rideau, Ottawa
and Madawaska districts. The area served is that part of Ontario lying east of
the area served by the Georgian Bay and Niagara systems.
The power supply is from developments owned by the Commission on the
Trent Canal system and on the Mississippi and Madawaska rivers. Power is
purchased from the Gatineau Power Company, the Rideau Power Company
and the Beach Estate at Iroquois.
The Commission controls or has an interest in a number of undeveloped
water-power sites on the Ottawa, Mississippi and Madawaska rivers, from which
sites additional power can be made available when warranted by the demand.
At present the growth of load is met by increased deliveries of power purchased
under contract with the Gatineau Power Company.
66 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
Owing to low water conditions on the Trent Canal system, the power allot-
ments due from the Gatineau Power Company were all required in the closing
months of this year.
General engineering assistance and advice was given to municipalities
concerning the management and operation of the various local distribution
systems.
Certain municipalities received special engineering advice and assistance
regarding a number of matters, which are more fully referred to as follows:
Bobcaygeon — Estimates on the cost of power were given to this munici-
pality last year but no action was taken by the municipal officials. This year a
further request was received from the municipality for new estimates. New
estimates based on present conditions were submitted.
Brockvllle — The Brockville Public Utilities Commission has this year paid
off all its debenture debt against the local utilities. This event was celebrated by
a banquet on October 12, 1933, at which the members of the Provincial
Commission were guests of honour.
Cobourg — The electrical distribution system and waterworks which were
purchased by the Corporation from the Commission last year, were managed
and operated by the Commission on behalf of the Corporation from January 1,
1932, to January 1, 1933, when the management and operation of these utilities
were taken over by the Cobourg Public Utilities Commission, which will operate
them, in future, on behalf of the Corporation.
Colborne — The corporation of Colborne concluded negotiations for the
purchase of the distribution system in the village from the Peebles Estate on
January 1 , 1933. From this date the system has been operated by the municipality
under a cost contract with this Commission.
Newcastle — An extension of the Newcastle distribution system to New-
castle-on-the-Lake authorized last year was completed and power made available
for the summer season.
Norwood— The rebuilding of part of the local distribution system, neces-
sitated by improvements to the highway, was completed by the Commission on
behalf of the municipality.
THUNDER BAY SYSTEM
An outstanding improvement has taken place in the demand for power on
this system during the year. A large portion of the load increase was not obtained
until near the end of the current year, but early in the new year the entire surplus
capacity of the two generating plants at Cameron Falls and Alexander will be
sold and the generating equipment of the combined developments on the Nipigon
river will be completely loaded for the first time since the completion of the
1934 HYDRO-ELECTRIC POWER COMMISSION 67
Alexander development. One of the large pulp and paper mills at Port Arthur,
formerly closed down, resumed operations during the last four months of the year,
and another large mill in Fort William increased its demand by several thousand
horsepower.
New load to the extent of approximately 40,000 horsepower was contracted
for, with two large pulp and paper mills for the operation of electric steam
generators. This new load was sold on an "at-will" basis and is recallable at
any time during the term of the agreements should the power be required for
supplying firm power to new or existing consumers. One of these steam generator
installations, with a demand of about 18,000 horsepower, was placed in operation
in September, and the installation of equipment under the other contract is nearly
completed and will probably be placed in operation during the first month of
the new year.
A large extension was made to the Port Arthur rural power district and
service was given to approximately 60 summer consumers situated along the
shores of Thunder Bay east of Port Arthur.
Engineering assistance and advice covering the management and operation
of the various distribution systems was given to the cities of Fort William and
Port Arthur, and to the village of Nipigon, and the complete operation of the
Port Arthur and Fort William rural power districts was carried on by the
Commission on behalf of the various townships concerned.
NORTHERN ONTARIO PROPERTIES
Nipissing District
This district comprises the area lying north and east of Lake Nipissing, and
is served by three generating plants, situated on the South river, supplying
electrical energy to the city of North Bay, the town of Powassan, the unincor-
porated hamlets of Callander and Nipissing and the rural districts adjacent to
North Bay and Powassan. Load conditions in this district were fairly constant
throughout the year, in consequence of which no special changes, or improvements
were required in generating plant, transformation, transmission, or distribution
equipment. Arrangements were made, however, to secure an additional 750-kv-a
in transformer capacity for North Bay to provide spare or emergency equipment
for future operation.
Abitibi District
This district comprises the entire area lying within transmission distance of
the Abitibi Canyon development, including the mining districts adjacent to
Sudbury, Kirkland Lake, and Timmins. During the year the Commission
became responsible for the operation of the Abitibi Canyon development and
transmission lines, formerly the property of The Ontario Power Service Cor-
poration. The Abitibi Canyon development was placed in operation during the
month of May, and an engineer was assigned to the Abitibi district in order to
maintain contact with all of the existing and prospective mining companies, for
the purpose of submitting information in connection with the use of electrical
68 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
energy and the cost thereof, and negotiating contracts for the sale of power.
Definite information was submitted to the officials of several new mining proper-
ties and details of agreement covering the sale of power were discussed. It is
expected that several agreements covering the delivery of electrical energy will
be closed with these mining companies early in the new year. A contract was
also completed with The Canada Northern Power Corporation covering the sale
of power by the Commission to the company of its entire future load growth for
a period of ten years. A large block of "at-will" power was sold to one of the large
paper companies under a temporary agreement, for electric steam generation,
and arrangements were made to negotiate a long-term contract with the same
company for 60,000 horsepower under similar conditions. It is anticipated that
the results of the efforts being made will require the construction of from 150 to
200 miles of high-tension transmission line, and of several transformer stations
early next year, to take care of local growth in this district.
Sudbury District
The district comprises the area adjacent to the city of Sudbury, to which
power is supplied at 60 cycles from three power developments on the Wahnapitae
river. The demand for 60-cycle power in this district has been such that the
power that can be produced by the generating capacity of these three develop-
ments has all been sold, and any further load increase will have to be taken care
of by 25-cycle power from the Abitibi Canyon development and transmission
line, or, by the installation of frequency changer sets. A new contract was nego-
tiated with one of the large mining companies, providing for an increased demand
of 50 per cent, and assistance was given to the city of Sudbury in connection with
the operation of its local distribution system. Information was also submitted
to the rural districts adjacent to Sudbury with respect to procedure concerning
the securing of Hydro-Electric service from the Commission.
Patricia District
Information and advice was given to the large gold mine, at present being
served from the Ear Falls development. A survey was made, estimates were
prepared, and negotiations carried on concerning the construction of a develop-
ment at the foot of Lake Joseph on the Albany river in connection with supplying
power to two mining properties.
Manitoulin District
This district comprises the entire Island of Manitoulin, and, at the present
time, power is being delivered to a rural power district, inclusive of the town of
Gore Bay, and the hamlet of Mindemoya. Meetings were held throughout the
year in the eastern section of the island adjacent to Little Current and Mani-
towaning, also Sheguindah, in connection with supplying these municipalities,
and adjacent rural sections, by means of any extension to the existing lines, or
by securing power from another development. At the present time power is
being purchased from the Kagawong development of The Little Rapids Pulp
Company under a contract which was executed during the year.
1934
HYDRO-ELECTRIC POWER COMMISSION
69
RURAL ELECTRICAL SERVICE IN ONTARIO
A cheese factory utilizing electric power — one of many rural industries that have experienced
the economy of "Hydro" service
RURAL ELECTRICAL SERVICE
There are now 171 operating rural power districts served by the Commission.
These districts deliver power to approximately 62,000 rural consumers in 352
townships and 92 police villages, over a network of rural primary lines which, in
length, aggregates more than 9,000 miles. In addition to the 352 townships
served, there are 8 townships served jointly by rural power districts and voted
areas. In the years prior to 1920 this service was supplied to townships and for
the most part the rural consumers were reached by extensions to existing urban
and suburban distribution networks. In 1920, amendments to The Power
Commission Act provided for the formation of rural power districts and in 1921
and 1924 special rural Acts were passed by the Provincial Legislature providing
for the payment of Provincial "grants-in-aid." These legislative enactments;
*the special consideration given to rural electrical service; and the experience
gained and put into practice by the Commission, have resulted in a remarkable
growth in rural electrical service in Ontario. This is well shown by the accom-
panying charts. There is, indeed, no branch of the Commission's activities to
which, during recent years, more detailed consideration has been given than its
department of rural electrical service.
*Re Rural Power District Legislation: — Consult The Power Commission Act (R.S.O. 1927,
ch. 57): The Rural Hydro-Electric Distribution Act ((R.S.O. 1927, ch. 59; The Rural Power District
Loans Act, 1930 (20 Geo. V, ch. 14), and The Rural Power District Service Charge Act, 1930 (20
Geo. V, ch. 15).
70
TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
RURAL ELECTRICAL
Hydro service brings to Ontario farms a higher standard of
in house, dairy and barn. Only those city people
farm under other methods can fully
Distribution of power to rural communities has now gained an established
place in Ontario country life. The improvements that can be effected in the
standard of living by the generous use of electricity on the farm and in the farm
home are everywhere recognized. It is clean for the house, convenient and safe
for all uses and under Hydro rates very economical. Even during the past two
years when the cumulative effects of the period of economic stress have been most
acutely felt, appreciable gains have been made in rural power districts both to
the number of consumers served and to the total mileage of lines.
It must, however, be recognized that rural electrical service is essentially a
community interest and to attain its greatest success must have the whole-
hearted support of all rural dwellers. Co-operation is the keynote of success.
Primarily, rural service is made possible by the great networks of transmission
lines which have been constructed to serve urban municipalities. These networks
afford a base from which rural primary lines may economically be extended over
wide areas of the more closely settled parts of rural Ontario. Thus there is
co-operation between the urban and rural citizens. The growth in the mileage of
rural lines during normal years has been phenomenal, until at the present time
the aggregate length of such lines exceeds the mileage of the main transmission
lines built to serve urban centres. In the rural power districts the transmission
lines which serve the individual farmers can also carry electrical energy to
churches, schools and stores, as well as provide power for factories utilizing
1934
HYDRO-ELECTRIC POWER COMMISSION
71
SERVICE IN ONTARIO
living with comfort and relief from many arduous tasks
who have had experience of life and work on the
appreciate the benefits of this service
agricultural products as their raw material. Thus, co-operation produces the
greatest benefit to all and results in lower costs.
In supplying electrical service to rural districts the Commission has followed
a comprehensive and carefully thought-out programme. Rural power districts
are designed to be economic unit areas with respect to the transmission lines and
power supply facilities that are available, and their boundaries are not arbitrary
geographical limits such, for example, as define the areas of townships. In practice
a typical district covers about 100 square miles.
The experience gained by the Commission and the improvements in tech-
nique enable electrical service to be given to rural districts when there can be
secured three signed farm contracts, or their equivalent, per mile of line to be
constructed.
Provincial Government Aids Rural Service
Assistance respecting electrical service is given by the Province to farmers
and rural residents in three ways, namely:
First — A grant-in-aid toward the initial capital cost of supplying electrical
service, amounting to 50 per cent of the cost of line and secondary equipment
necessary to deliver power from the supply point of the Commission's stations
or of a city, town, village, etc., to the customer's property. This is the maximum
amount provided for by The Rural Hydro-Electric Distribution Act.
72 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
Second — Authority has been granted by the Province to the Commission in
The Rural Power District Service Charge Act, J 930, to fix a maximum service charge
for any class of service rendered by the Commission in a rural power district.
Where as may be the case in newly established rural power districts such maximum
service charge is not sufficient to meet the necessary cost of service, as specified
by the Commission, the deficit is chargeable to and payable out of the Consoli-
dated Revenue Fund of the Province. Payments made out of the Consolidated
Revenue Fund for this purpose, on account of any rural power district, are
charged to that rural power district in a special account — known as the "Rural
Power Service Suspense Account" — in the books of the Treasurer of Ontario,
and any surplus thereafter arising from any maximum service charge in that
rural power district is to be paid to the Treasurer of Ontario and placed to the
credit of the rural power district in such suspense account until the deficit is
extinguished. Where a temporary deficit arises in any rural power district owing
to the application of the maximum service charge, such maximum service charge
must remain in force and be charged in that rural power district until the deficit
is extinguished.
A tabulation set out on an accompanying page shows the present maximum
service charge placed in effect on January 1, 1930.
Third — An Act — The Rural Power District Loans Act, 1930 — to provide for
granting aid towards the installation of electrical works in rural power districts
was passed during the year 1930. The purpose of this Act is to provide advances
towards the installation of electrical services in rural power districts, subject to
regulations. Aid may be granted subject to such regulations and repayments, or
the wiring from the transmission or distribution lines of the Commission into and
throughout dwellings, farms, out-houses, and any other works which may from
time to time be specified by the regulations. In addition to the wiring, loans may
be obtained on transformers, motors, or other appliances, as may be necessary or
expedient for any industrial, agricultural or domestic purpose which may be
specified in the regulations.
Rural Loans
Loans have been made to rural consumers to aid them finance the cost of
wiring their premises and the installation of motors, grain grinders, pumping
systems, milking machines and washing machines — all made possible by the
passing of The Rural Power District Loans Act in 1930.
Up to October 31, 1933, there have been 496 applications for loans received
since the Act was put into force. Of these 144 were received during the last
fiscal year. During the fiscal year 11 applications have been withdrawn by the
applicants, 12 have been either ineligible for loan due to the condition of the
security or the applicants have failed to conform to the regulations — approval to
these has not been given — and 29 applications are pending the receipt of informa-
tion from the field to enable the Commission to approve them. In all, 371 appli-
cations have been approved and loans granted up to October 31, 1933; of these,
110 have been granted during the past fiscal year.
1934
HYDRO-ELECTRIC POWER COMMISSION
73
The following table shows the applications approved and granted in the
various systems:
APPLICATIONS FOR RURAL LOANS APPROVED AND GRANTED
System
To Oct. 31, 1932
Fiscal Year 1933
Total to date
No.
Amount
No.
Amount
No.
Amount
Niagara
166
76
19
$
36,260
21,727
5,715
93
9
3
5
$
17,135
2,065
415
1,060
259
85
22
5
$
53,395
Georgian Bay
23,792
Eastern Ontario
6,130
Northern Districts — Manitoulin Island
1,060
Totals
261
63,702
110
20,675
371
84,377
The average loan amounts to $227.43.
DETAILS OF RURAL LOANS GRANTED UP TO OCTOBER 31, 1933
Items applied for
(including installa-
tion) in loans
1930-31
74 Applications
Granted
1931-32
187 Applications
Granted
1932-33
110 Applications
Granted
Totals
All Applications
Granted
which have been
paid
Number
affected
Cost to
consumers
Number
affected
Cost to
consumers
Number
affected
Cost to
consumers
Number
affected
Cost to
consumers
Service
60
63
60
16
15
6
2
15
$
3,485
7,861
6,160
1,545
2,490
616
675
1,734
91
90
87
15
95
8
2
8
$
4,756
8,077
7,453
1,508
16,986
849
405
934
21
18
24
7
87
2
2
2
$
1,286
1,279
1,470
942
15,635
147
386
159
172
171
171
38
197
16
6
25
$
9,527
17,217
15,083
3,995
House wiring
Building wiring. . . .
Motors
Grain grinders
Pumping systems. .
Milking machines..
Washing machines.
35,111
1,613
1,466
2,827
Totals
74
24,566
187
40,968
110
21,304
371
86,839
Respecting the 371 applications which have been granted, the following
table shows the number of loans approved for each term of years from one to
ten years:
One year term 4 loans
Two " " 4 "
Three " " 24 a
Four " " 11 »
Five " " 203 "
Six year term 6 loans
Seven a " 72 "
Eight " " 9 "
Nine " " "
Ten " " 38 "
Total 371 "
Up to October 31, 1933, 29 loans had been repaid in full, either through the
fact that the loans matured or because of the improved financial position of the
loanee.
The assistance given by the Province in these several ways is in pursuance of
a long-established governmental policy of promoting the basic industry of agri-
culture. This policy had previously found expression in the establishment of
74
TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
RURAL ELECTRICAL SERVICE IN ONTARIO
The utility-motor chopper set up as shown permits chopping to be
done while the operator is otherwise employed in the barn The
line shafting, when belted to the motor, will supply power for
many other machines used in the barn
agricultural schools, colleges and experimental farms, in assistance for farm
drainage, road building and in other ways. The grants-in-aid and guarantees
thus given make it possible to extend hydro-electrical power service to those
engaged in and connected with agricultural pursuits in less densely populated
districts where otherwise such service would not be financially feasible.
The extent and effect of the Province's financial assistance with respect to
the distribution of power in rural districts should be clearly understood. The
Government grant-in-aid relates solely to the initial capital investment for dis-
tribution facilities in rural power districts only. Having made its grant-in-aid,
the Government further participates in the operation of each district in that it
guarantees a maximum service charge, otherwise its participation in the operation
of the property ceases. Each rural power district not only pays the cost of
operation, maintenance and administration of its lines, but also sets up reserves
for renewals, obsolescence and contingencies on the whole of the equipment and
lines, as well as for sinking fund on the investment made by the Commission
on behalf of the townships served.
The aggregate load distributed to the rural dwellers is, and possibly must
always be, but a relatively small proportion of the total load distributed by the
1934
HYDRO-ELECTRIC POWER COMMISSION
75
RURAL ELECTRICAL SERVICE IN ONTARIO
Milk cooling by electric refrigeration with agitation is now being used by progressive Ontario
farmers to their economic advantage. It is reported that this method of cooling is less
expensive, more reliable and certainly cleaner than ice
Commission when the amounts of power supplied to large cities and industrial
consumers are taken into consideration, but some idea of the magnitude of the
rural load may be conveyed by stating that it is now equal to the sum of the loads
supplied to eight of the smaller cities served by the Commission, or to the loads
supplied to 38 towns of population 2,000 or more.
The accompanying diagrams and tables illustrate the expansion of rural
electrical service in Ontario during the last thirteen years. The greater area
covered is shown by the increased mileage of primary lines approved. The
increase in the use of electricity by the farming communities is shown by the
aggregate power loads supplied to the rural power districts. It is believed that
further substantial progress will be made in the next few years. An outstanding
reason for this growth is the extent to which the Commission has gained the
confidence of the rural communities through efficiency in the construction of
lines, through progressive reductions in rates and by a continuity of service which
has contributed very materially to progress by inspiring confidence in the use of
electrical power-driven machinery.
Further research investigation of equipment for use on the farm has been
carried on by the Commission's engineers in an effort to improve the efficiency
of the application of Hydro power to the needs of the Ontario farmer and to
develop new uses to their advantage. Plates for grain choppers have been
further improved and new developments in the utility motor chopper have been
started by manufacturers in co-operation with the Commission. Milk coolers
employing the agitation principle have been produced which achieve the desired
76
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
MILES
15.000
10.000
5.000
JAN
FEB
MAR
APR
MAY
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
JAN
FEB
MAM
APR
MAY
JUNE
JULY
AUG
SEPT
OCT
NOV
OEC
FEB
MAR
APR
MAY
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
JAN
FEB
MAR
APR
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JUNE
JULY
AUG
SEPT
OCT
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DEC
JAN
FEB
MAR
APR
MAY
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
t 1 M 1 II M M II M M II | M M M M M " ~-
i j RURAL POWER DISTRICTS
TOTAl Mil FAflF OF
RURAL PRIMARY LINES APPROVED
ALL SYSTEMS
HYDRO-ELECTRIC POWER COMMISSION
OF ONTARIO
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-- 'T
FEB
MAR
APR
MAY
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
FEB
MAR
APR
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
FEB
MAR
APR
JUNE
AUG
SEPT
OCT
NOV
DEC
JAN
FEB
MAR
APR
MAY
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
JAN
FEB
MAR
APR
MAY
JUNE
AUG
SEPT
OCT
NOV
DEC
15,000
10,000
5.000
RURAL T LINE EXTENSIONS DURING THE YEAR 1933
Miles of
primary-
line
Number of consumers
Power
supplied
in
October,
1933
Capital approved for
extensions
System
Hamlet
Farm
Total
Total
Provincial
grant-in-aid
Niagara
113.76
40.23
58.74
26.65
2.73
4.40
775
312
3C7
55
23
43
512
118
154
5
1
6
1,287
430
461
60
24
49
24,296
2,473
5,329
113
81
80
$ c
274,682.00'
101,482.94
151,051.00
48,183.00
7,086.00
8,377.00
$ c
137,341.00'
Georgian Bay
Eastern Ontario. . . .
Thunder Bay
Northern Ontario
Properties:
Nipissing District
Manitoulin District
50,741.47
75,525.50
24,091.50
3,543.00
4,188.50
Total
246.51
1,515
796
2,311
32,372
590,861 .94
295,430.97
1934
HYDRO-ELECTRIC POWER COMMISSION
77
HORSEPOWER
HORSEPOWER
60.000
i
>
>
JAN
FEB
MAR
APR
MAY
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
JAN
FEB
MAR
APR
MAY
JUNE
JULY
AUO
SEPT
OCT
NOV
DEC
JAN
FEB
MAR
APR
MAY
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
JAN
FEB
MAR
APR
MAY
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
JAN
FEB
MAR
APR
MAY
JUNE
JULY
AUQ
SEPT
OCT
NOV
DEC
uu.uuu ; " ■ I I I I l l l l I I i i i i i I I l l l l i l
A^ftRF^ATF PFAK" 1 flAn^
ALL SYSTEMS
HYDRO-ELECTRIC POWER COMMISSION
OF ONTARIO
1QOO
1 Q0 1 W> j*-
1931 ' f A f S
I \ 4- \— - i- -^ - qWo-
I ^\ / > t yJ °
30.000 -"\ V -j-
V 4 W ^J 1Q9Q J N
V / 1
y. ^ ti i
t >> \ '
IU.UUU - - "Ii7^0" ~j ~^sJj "
1Q07. / V _A
J C. 1 ~S" ^-7
- QPfi £"^ ^-£
l9fcO r ^^
-n^ -1Q9/1
iQOO 1 1 ?*"""* > **
rr+t '92i 1 1 1 1 1 NniUil^kftiTm
FEB ~
MAR
APR _
MAY
JUNE
JULY
AUG
SEPT
OCT ~
NOV
DEC
JAN
FEB
MAR
APR
MAY
JUNE
JULY J
AUG J
SEPT 1
OCT
NOV
DEC
FEB ~
MAR
APR
JUNE ~~
JULY _
AUG
SEPT
OCT
NOV
DEC ~~
JAN _
FEB _
MAR _
APR _
JUNE _
JULY _
AUG
SEPT
OCT
NOV
DEC —
JAN _
FEB _
APR ~
MAY _
JUNE _
JULY
AUG
SEPT
OCT
NOV
DEC —
50.000
40.000
30.000
20.000
10,000
SUMMARY OF RURAL LINE EXTENSIONS
As Approved by the Commission from June 1, 1921, to October 31, 1933
System
Miles of
primary
line
Number of consumers
Capital approved for extensions
Hamlet
Farm
Total
Total
Provincial
grant-in-aid
Niagara
Georgian Bay
Eastern Ontario
Thunder Bay
Northern Ontario Proper-
ties:
Nipissing District
Manitoulin District. . .
Total
6,581.34
22,405
22,135
44,540
826.18
4,044
1,777
5,821
1,637.16
6,769
3,969
10,738
77.20
111
150
261
15.12
293
29
322
37.40
143
20
163
9,174.40
33,765
28,080
61,845
* c
14,528,882.63
1,726,687.95
3,612,244.79
135,300.00
44,094.00
62,923.00
20,110,132.37
$ c
7,241,161.31
829,681.99
1,806,122.39
67,650.00
22,047.00
31,461.50
9,998,124.19
78 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
result in a minimum of time. The Commission's engineers, in co-operation with
the Agricultural Engineering department of the Ontario Agricultural College at
Guelph, have jointly made studies and suggestions in the perfecting of this
equipment.
During the past year electrical soil heating was the subject of research in
regard to its use on vegetable growers' farms at Burlington, Vineland Testing
station and the Ontario Agricultural College. Investigations were also made in
order to show the variety of uses to which electrical soil heating might be applied
by vegetable growers, florists, etc. These investigations were actually carried
out in the tobacco seed propagating beds at Simcoe, in the propagating flower
beds at Niagara Falls, also in the open vegetable fields in the vicinity of
Collingwood and Burlington.
Co-operation with the Ontario Government Emphasizing the
Importance of "Ontario Products for Ontario People"
The Ontario Department of Agriculture arranged during the year to conduct
cooking schools in various centres throughout the Province. These schools were
for the purpose of emphasizing the importance of "Ontario Products for Ontario
People." At the request of the Minister of Agriculture the Commission co-
operated with the Department by setting up for demonstration purposes electrical
apparatus for the kitchen such as cooking appliances, refrigerators, etc. This
equipment was loaned by the various manufacturers and two-day electric cooking
demonstrations were held in various centres as follows: Aylmer, Brampton,
Brighton, Exeter, Lindsay, Milton, Napanee, Newmarket, Orangeville, Port
Hope, St. Marys and Stratford.
Considerable interest in the information provided was apparent as these
classes had an average attendance of 250. In two cases severe weather interfered
with the attendance. The places at which these demonstrations were given were
selected with a view to providing information for the smaller towns and rural
districts; as it was considered that the cities and larger towns were already well
informed through demonstrations by the various manufacturers of electrical
apparatus.
The Year's Constructional Activities
During the past year the amount of constructional work carried out in the
rural power districts was much lower than that obtaining a few years ago. Never-
theless some 250 miles of primary transmission lines were constructed or under
construction and electrical service was given to more than 2,300 additional
consumers. The capital expenditure approved for rural construction work during
the past year was $590,862, and the aggregate peak load in October, 1933, reached
32,372 horsepower. Details of these matters and of the present status of rural
distribution are presented in the accompanying tables. For the coming year,
arrangements have been made to construct about 300 miles of additional rural
lines.
The tabulation on page 76 shows the extensions approved during the year,
the number of consumers, the amounts of power supplied, the capital expenditures
and the amounts of provincial grant-in-aid of rural lines approved by the
Government.
1934
HYDRO-ELECTRIC POWER COMMISSION
79
RURAL ELECTRICAL SERVICE IN ONTARIO
Electric soil heating by cable heater units installed on or under the soil of propagation or
growing areas, produces surprising results in advancing and increasing the harvest. Control,
automatically or at the will of the operator, provides flexibility formally not available to the
grower. This is a comparatively new field of application for Hydro-electric power
Rates for Rural Electrical Service
Rates to rural consumers are based upon service "at cost" — proper account,
of course, being taken of the Provincial grant-in-aid for rural work and the
operation of the provision for a maximum service charge — and as in urban centres
the rates are made up of two parts, a service charge and a consumption charge.
In any given rural power district the service charge to a consumer depends
primarily upon the individual connected load or demand which determines his
class rating (see "Classification of Services") but this is modified in the earlier
years of operation of a rural power district by the provision respecting maximum
service charge; the consumption charge is in the form of a first and second
kilowatt-hour charge and is largely determined by the cost of power at the source
of supply to the rural power district.
An important factor in connection with rural power supply is the stability
of rates charged. Since service is given at cost and since it is the policy to give
service whenever economically practicable, it is necessary, in the interests of the
rural consumers themselves, to ensure by contract a certain minimum return
from each mile of line constructed. Otherwise, if one or two prospective consumers
failed to take service, it would place an unfair burden upon those who did.
Experience has led the Commission to adopt the safe policy of constructing rural
lines only when sufficient contracts have been signed to guarantee payment of the
80
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
RURAL ELECTRICAL SERVICE IN ONTARIO
In this installation the saw is being driven by a 3- horse- power motor. The motor can also
be belted to the chopper or to a lineshaft for driving other power-using equipment. Belted-
motor chopper installations are in many cases being superseded by utility-motor choppers
requiring only half the power
fixed charges on their cost; the minimum signed contracts required being three
ordinary farm contracts or their equivalent per mile of line constructed.
For the purpose of determining the service charge, each mile of line is assumed
to represent a minimum of 15 units and to each class of service is assigned a
value in such units. The accompanying table gives this information and shows
the annual and monthly service charges applicable to each class of service. It
may be stated that more than 90 per cent of the contracts entered into for farm
service are either of Class 2B or Class III. These, therefore, are the representative
classes for individual farm service.
Rather more than half the consumers in rural power districts are grouped in
hamlets or small villages closely identified with rural activities, and these con-
sumers are usually in Class IB or Class 1C. It should further be understood that
rural power districts do not include suburban districts or larger villages. These
have their own electrical utilities.
Usually new rural power districts begin at standard rural rates and these
constitute the maximum rates submitted to the proposed consumers. As the
average number of consumers per mile of line increases, the service charges may
be, and in practice have been, reduced; and with increased consumption the
rates per kilowatt-hour are also lowered. Thus, in older-established rural power
districts the total cost of service is much below the initial standard rates.
At the end of this section is given a tabulation of the rural power districts
established in connection with the several systems of the Commission, which
shows the miles of line, the number of consumers and the rate schedules for each
district.
1934
HYDRO-ELECTRIC POWER COMMISSION
81
RURAL ELECTRICAL SERVICE IN ONTARIO
Present pumps may be adapted to electric
drive by using a jack belted to a motor,
usually with a supply tank at a height
The automatic electric pump used in rural
districts, assures a water service equal to
that in towns and cities. In the equipment
shown, the pump is automatically started
when the pressure in the small tank falls
below a certain level
SERVICE CHARGES IN RURAL POWER DISTRICTS— SINCE JAN. 1, 1930
With Provincial Grant-in-Aid — 25-cycle and 60-cycle Service
Approx.
Kilowatt-
Class
Units
number
Demand
hours
Gross
Gross
Net
Net
of
per
of
allowed
per
annual
monthly
annual
monthly
rural
con-
customers
consumer
month
service
service
service
service
service
sumer*
per mile
of line
in k-w.
at
first rate
charge
charge
charge
charge
$ c.
$ c.
$ c.
$ c.
IB
2.25
6.8
1.32
30
18.00
1.50
16.20
1.35
1C
3.75
4.0
2.0
30
27.96
2.33
25.20
2.10
2A
1.90
8.0
1.32
30
20.64
1.72
18.60
1.55
2B
3.50
4.3
2.0
30
27.96
2.33
25.20
2.10
3
5 00
3
3.0
42
33 36
2.78
30 00
2.50
4
5.35
2.8
5.0
70
36.00
3.00
32.40
2.70
5
7.50
2.0
5.0
70
50.04
4.17
45.00
3.75
6A
12.50
1.2
9.0
126
62.04
5.17
55.80
4.65
6B
12.50
1.2
9.0
126
70.68
5.89
63.60
5.30
7A
20.00
0.74
15.0
210
92.64
7.72
83.40
6.95
7B
20.00
0.7
15.0
210
111.36
9.28
100.20
8.35
*Before a rural primary line is constructed contracts equivalent to 15 primary units per
mile must be signed. (For explanation of units see accompanying text.) Thus three Class 3
consumers at 5 units each equals 15 units. Service charges are adjusted so that each class of
service bears its equitable share of the cost.
Note: For classification of services see page 88.
82
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
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HYDRO-ELECTRIC POWER COMMISSION
83
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88
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
CLASSIFICATION OF SERVICES FOR RURAL POWER DISTRICTS
When contracts between the consumer and the township have been executed,
users of power in townships are supplied with electric service under general classes
with limitations as follows:
Class
Service
Class
demand
kilowatts
Phase
Volts
Fuse rating
amperes
(maximum)
IB
1C
2A
2B
3
4
5
6A
6B
7A
7B
Hamlet Lighting
u a
House Lighting
Small Farm Service. . .
Light Farm Service .
Medium Farm Service
u u a
Heavy Farm Service. .
a u u
Special Farm Service. .
1.32
2
1.32
2
3
5
5
9
9
15
15
1
1
1
1
1
1
3
1
1 and
1
1 and
110
220/110
110
220/110
220/110
220/110
220/110
220/110
220/110
220/110
220/110
15
35
20
35
35
50
35
100
60
According to load
According to load
Class 1: Hamlet Service — Includes service in hamlets, where four or more consumers are
served from one transformer. This class excludes farmers and power users. Service is given
under two sub-classes as follows:
Class 1-B: Service to residences or stores. Use of appliances over 1,320 watts
permanently installed is not permitted under this class.
Class 1-C: Service to residences or stores with electric range or permanently installed
appliances greater than 1,320 watts. Combinations of residence and store supplied from
one service shall be not less than Class 1-C. Special or unusual loads will be treated
specially.
Class 2A: House Lighting — Includes service to all residences that cannot be grouped
as in Class I. This class excludes farmers and power users.
Class 2B: Farm Service, Small — Includes service for lighting of buildings and power for
miscellaneous small equipment and power for a single-phase motor not exceeding 2 horsepower
or an electric range (motor and range not to be used simultaneously) on a small farm of fifty
acres or less.
Class 3: Farm Service, Light — Includes service for lighting of farm buildings,
power for miscellaneous small equipment, power for single-phase motors not exceeding
3 horsepower and electric range. Range and motor are not to be used simultaneously.
Class 4: Farm Service, Medium Single-Phase— Includes service for lighting of farm buildings
and power for miscellaneous small equipment, power for single-phase motors up to 5-horsepower
demand or an electric range. Range and motor are not to be used simultaneously.
Class 5: Farm Service, Medium 3-Phase — Includes service for lighting farm buildings
and power for miscellaneous small equipment, power for 3-phase motors, up to 5-horsepower
demand, or an electric range. Range and motor are not to be used simultaneously.
Class 6: Farm Service, Heavy — Includes service for lighting of farm buildings and power
for miscellaneous small equipment, power for motors up to 5-horsepower demand and an electric
range, or 10-horsepower demand without an electric range. Single- or three-phase service will
be given at the discretion of the Hydro-Electric Power Commission of Ontario.
Class 7: Farm Service Special — Includes service for lighting of farm buildings, power
for miscellaneous small equipment, power for 3-phase motors from 10- to 20-horsepower demand
and electric range. Single or three-phase service will be given at the discretion of the Hydro-
Electric Power Commission of Ontario.
Note: Class 2B is the service usually supplied to small farms of fifty acres or less and Class 3
is the service usually supplied to ordinary farms of larger size. More than 90 per cent of new
contracts for farm service are in one or other of these two classes.
1934 HYDRO-ELECTRIC POWER COMMISSION 89
SECTION IV
HYDRAULIC ENGINEERING AND CONSTRUCTION
The advancement of the Abitibi Canyon development to the operating stage
was responsible for the major items of design and construction during the year.
After resuming construction as the agent of the receiver for the company, after
financial difficulties had caused a cessation of work, the Commission carried on
when the province of Ontario acquired the development.
The original plans of the company provided for the immediate completion
of the whole development, which was designed to accommodate five units of
66,000 horsepower each. The major part of the work was completed before the
shut-down referred to above, the dam, wing walls, sluices, high water channel
and power house substructure being practically completed. The programme,
as modified after the Province acquired the property, provided for the completion
of two units to the operating stage, and other necessary work in connection
therewith. The units came into service and delivered commercial power in the
summer of 1933.
At the Niagara Falls plants, only minor items of construction, completing
work commenced in the previous year, required attention. At Chats falls,
extensive efficiency and capacity tests were conducted. The arbitration in
connection with the Kingdon Mining and Smelting company involved a large
amount of field and office work as assistance to the Legal department.
In the Georgian Bay system, repairs were made to the dam at Walkerton,
and investigations were made of wood-stave pipe joints, preparatory to the
reconstruction of No. 1 wood-stave conduit at the Eugenia development. Repairs
were also made to concrete in the dam at Nipigon.
At the request of the Public Utilities commission of the town of Almonte,
plans and specifications were prepared for an extension of the town's power plant
by the installation of an additional unit. The Commission's engineers also gave
advice during the completion of the contract for the new equipment, and made
inspections during its fabrication.
Surveys were made and plans and estimates prepared in connection with
the construction of a development to supply power to mining properties in the
district of Patricia.
Further assistance was given to the Department of Lands and Mines in
connection with the Grand river conservation scheme.
90 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
NIAGARA SYSTEM
Queenston-Chippawa Development
The end of the last fiscal year found certain minor works in progress on the
Queenston-Chippawa development, which were completed shortly after that time.
Among these were repairs to the Michigan Central Railroad bridge over the power
canal at Montrose, and work on the Victoria Avenue bridge.
Ontario Power Plant
At the Ontario Power plant, scaling of loose rock from the cliff behind the
generating station continued, and was completed at the end of December. A dry
stone wall was also built on the rear wall backfill to protect the power house
roof from any material on the cliff that may become loosened by weathering and
be dislodged. This and certain site improvements were completed early in
January.
An inspection of the steel plate of certain of the penstocks was made, and a
report prepared on the protective measures to retard deterioration of the outer
surface. The penstocks at the Ontario Power plant are erected in shafts and
tunnels, extending downward and outward from the three main conduits. Five
shafts and tunnels house penstocks Nos. 1 to 10, two in each tunnel. In a number
of the tunnels, the void around the penstocks has been filled with concrete to
protect the penstocks. The inspection referred to was carried out in the other
tunnels, for the purpose of determining the necessity, and the measures to be
adopted, for preservation of the unprotected penstocks.
Chats Falls Development
Only minor items of construction work were carried out during the past year,
the plant having been completed during the previous year. Hydraulic tests of
various kinds were conducted, having in view the determination of the turbine
capacity and efficiency, the plant capacity under low head, and the plant capacity
at periods of low flow.
Turbine efficiency and capacity tests were conducted on unit No. 3. Units
4, 7 and 8 had been tested in the previous year, and on these, consistent results
were obtained. The tests on unit No. 3 confirmed the results obtained on the
other units.
The quantity of water used per unit at this plant is in excess of 6,000 cubic
feet per second at full gate. The quantity of water to be measured and the design
of the plant combined to make accurate measurements more difficult than is
usually the case. The Gibson time-pressure method of water measurement had
been applied in the majority of the tests conducted by the Commission, especially
in those cases where a reasonable length of supply pipe was available within which
the method might be applied. The supply pipes at Chats falls are much shorter
than any in which the method had been used previously, but application of the
method proved to be quite successful, in fact the results obtained on the different
units were unusually consistent. The results of these tests, in addition to deter-
mining that the turbines met the manufacturers' guarantees, provide information
1934
HYDRO-ELECTRIC POWER COMMISSION
91
WALKERTON DAM— SAUGEEN RIVER
Spillway and apron cribs
of great value in connection with operation of the plant to obtain the maximum
output from the available quantity of water. The tests also permit accurate
records of river discharge to be kept.
Assistance was given to the Legal department in connection with the arbitra-
tion on the claims of the Kingdon Mining and Smelting company for compensation
for lands expropriated and for damages to lands and mining properties. The
hearings in connection with this arbitration lasted for more than sixty days, and
involved a very great amount of computation and field work on the part of this
department.
GEORGIAN BAY SYSTEM
Inspection of the wood-stave conduit installed in 1914 at the Eugenia develop-
ment indicates that its replacement will be necessary in the near future. The
Commission's experience during the past twenty years with wood-stave pipes has
indicated certain weaknesses in the usual type of end joints used. Accordingly,
with the co-operation of manufacturers, investigations have been proceeding for
some months on designs and devices to overcome the tendency of the stave ends
to split or rot. It is proposed to build a section of pipe incorporating the various
designs of joints, and subject it to suitable tests.
Repairs were carried out on the dam on the Saugeen river at Walkerton.
Erosion under and downstream from the dam allowed leakage to take place
equivalent to the water capacity of one of the turbine units. Several attempts
to plug the leak have been made by former owners, but in none of these was
anything more than temporary relief obtained.
92
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
As the erosion had taken place in the vicinity of the original sluiceways, the
sluiceway was closed and converted into a spillway, below which apron cribs were
built. Cribs were built on the east bank to protect the land there from erosion
when the sluiceways are open. Protecting cribs were built also in an eroded area
downstream from the sluiceways.
A disused narrow-gauge railway bridge near the Hanover plant, communi-
cating with marl beds west of the river, which created a flood hazard, was removed.
ABITIBI CANYON POWER DEVELOPMENT
Forebay, dam and sluice gate from west shore above dai
NORTHERN ONTARIO PROPERTIES
Abitibi Canyon Development
The major items of construction work during the year were in connection
with the Abitibi Canyon development, which has now reached the operating
stage. This development, on the Abitibi river, is situated near Fraserdale,
sixty-five miles northerly from Cochrane. Construction was commenced in
1930 by the Ontario Power Service corporation, a subsidiary of the Abitibi
Power and Paper company. Active construction ceased in the summer of 1932,
due to financial difficulties. The Ontario Power Service corporation was placed
in a receivership in November, 1932, and construction of the Canyon develop-
ment was continued by the Commission for the Receiver until the development
was taken over by the province of Ontario early in 1933.
Active construction commenced in August, 1930, and by July, 1932, when
financial difficulties caused the work to be shut down, the plant was rapidly
nearing completion. The concrete in principal structures was all in place, except
for about 850 cubic yards in the dam, the wing walls at each end of the dam,
and a small protection wall on the down-stream side of the dam. An additional
3,000 cubic yards of concrete was required for bulkheads behind the closure
gates in the unwatering tunnels, and tailrace excavation to the extent of 57,000
1934
HYDRO-ELECTRIC POWER COMMISSION
93
ABITIBI CANYON POWER DEVELOPMENT
High water channel, looking downstream to river
ABITIBI CANYON POWER DEVELOPMENT
Tailrace from Power House — December, 1933
94
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
1934 HYDRO-ELECTRIC POWER COMMISSION 95
cubic yards was still to be removed. The erection of the hydraulic units and
equipment was about 70 per cent completed, and nearly everything was delivered
for units 1 to 4, as well as a large part of unit No. 5. Delivery and erection of
electrical equipment was not as far advanced. The power house roof and part
of the downstream wall were temporary structures only.
The decision was reached to continue construction so far as to place two
units in operating condition, the equipment for the remaining three units being
stored at the development, to be used when load conditions required their
installation. Work was prosecuted vigorously from the beginning of the fiscal
year, November 1, 1932, and by the end of March the tailrace excavation was
completed and the cofferdam and rock at the lower end of the tailrace removed
by blasting. The power house superstructure was practically completed, with
the exception of the application of the roofing material and the guniting of the
slabs over the penstocks.
Good progress had been made on the installation of equipment. Turbine
unit No. 1 was in place and aligned, the generator unit in place, and the bearing
being assembled. All governor piping in the turbine pit, including servomotors,
had been opened up and thoroughly cleared, and the cleaning of the governor
piping above the power house floor was in progress. Work was proceeding on
unit No. 2.
Unit No. 1 was turned over for the first time on May 4, and delivered
commercial load on May 24, 1933. No. 2 unit was placed in service on August
27, 1933. A description of the development follows.
The Abitibi Canyon development is situated on the Abitibi river in the
James Bay drainage area, about sixty-five miles northerly from Cochrane. The
river drains an area of 8,440 square miles above the power site, and has an
estimated average flow of more than 9,000 cubic feet per second. The site
possesses natural advantages for the construction of a power development, in
that the river channel there is confined to a narrow gorge, the rock walls of
which rise about 170 feet above the river bed. The dam concentrates the natural
fall in about six miles of river upstream therefrom, and the tailrace excavation
regains most of the fall from the dam site to the pool at the head of Eleanor
rapids, about three-quarters of a mile downstream. The normal headwater
level will be 641, and normal tailwater 401, and the head 240 feet. The
accompanying plan supplements this description and shows the relative positions
of the various structures and waterways.
The dam is a concrete gravity type structure, extending across the main
section of the canyon, with a sluiceway section adjoining it at the easterly end.
The closure is completed by a concrete retaining wall and rolled earth fill at
the west end of the dam, and a similar retaining wall and earth fill at the east
end of the sluiceway section.
The sluiceway section, which is designed to discharge the maximum
anticipated flood discharge of the river, consists of five gates, each having a
clear opening of 45 feet, with sills at elevation 616, each provided with an
independent motor-driven hoist. Heaters are provided for the checks, and
space heaters in the gates, which are sheeted on the downstream face, to assure
96 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
satisfactory winter operation. The sluiceways discharge into a high water
channel, extending for about 3,000 feet along the east bank of the river, and
discharging into the pool above Eleanor rapids. The high water channel is
located well back from the edge of the east bank of the canyon . and is formed
partly by excavation in rock and partly by the construction of gravity wall
sections along the sides where necessary to prevent overtopping.
The power house extends completely across the gorge and adjoins the main
dam section. The generator room is about 250 feet by 50 feet, and in the rear
of this, partly superimposed on the lower slope of the dam, is accommodation
for control room, offices, low tension switching, machine shop, pumps and other
auxiliaries. An elevator in a shaft on a slope, which conforms to the downstream
face of the dam, extends from the turbine deck to the headworks.
The power house is designed for an ultimate installation of five main units,
two of which are now completed. Each of the turbines has a rated capacity of
66,000 horsepower at 150 r.p.m. under a net head of 237 feet. Each turbine
is equipped with an 18-foot steel plate penstock, the intake being located in the
upper portion of the gravity section of the main dam, whence the penstocks
lead down from the face of the dam to the power house substructure, where they
are joined to the steel plate scroll cases incorporated therein. The penstocks
are protected from low temperatures by a continuous roof, which extends over
the entire penstock area. This roof is supported on steel columns, and consists
of I-beam purlins carrying aerocrete slabs, which are protected from the weather
by a heavy coating of gunite.
Each turbine is directly connected to a 45,000 kv-a., 85-per-cent-power-
factor, 13,800-volt, 25-cycle generator, with main and sub-exciters.
The plant is served by a standard gauge railway spur from the site to
Fraserdale, where it joins the T. and N.O. railway. Accommodation for the
operating staff is provided in houses erected on high ground on the west bank
of the river.
HYDRAULIC INVESTIGATIONS
Mississippi River
During the year, the Public Utilities commission of the town of Almonte
asked for engineering assistance in connection with an extension of its power
development on the Mississippi river within the town. The town owns two
plants, only one of which is operated at present. This plant contains a single
unit, having a turbine with a rated capacity of 550 horsepower and 550-kv.a.
generator, but the power canal and power house substructure are designed for
the installation of a second unit.
The Commission's engineers made an examination of the existing plants,
and gave advice as to the type of equipment that would be most suitable for
the town's requirements. Following this, plans and specifications were prepared
1934
HYDRO-ELECTRIC POWER COMMISSION
97
KAGAMI FALLS— ALBANY RIVER
An undeveloped power site in Northern Ontario
covering one 650 horsepower (30-foot head) turbine and generator, with governor
and other appurtenances. Tenders were called for on this equipment and advice
given in connection with the completion of the contract and inspections made
throughout the period of fabrication of the equipment.
Albany River
Pursuant to requests for studies and estimates for power supply required
by certain mining properties in the district of Patricia, preliminary surveys
were made of three possible power developments on the Albany river. The
locality for which a power supply is desired lies about ninety miles by aeroplane
north of Savant lake station on the Canadian National railway, and one hundred
and twenty miles by winter road.
Three power sites on the Albany river, about twenty-five miles south of
the properties to be served with power, were investigated in the summer of
1933, and preliminary surveys made, with a view to estimating the cost of
developing about 1,000 horsepower, the anticipated demand of the district.
The three sites surveyed are Cedar rapids, at the outlet of lake St. Joseph, and
Triple falls and Kagami falls, respectively twenty and twenty-five miles down-
stream. At each of the first two, the available head is 15 feet, and at Kagami
falls 21 feet. Transportation of material and equipment to the sites is difficult
and expensive. Heavy parts may be taken in only by winter road; for general
supplies, aeroplanes may be utilized. The plants, therefore, are designed as
far as possible to reduce transportation costs. Preliminary designs and estimates
have been prepared.
98 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
Grand River Flood Prevention
Assistance was given to the Department of Lands and Forests of the
province of Ontario in connection with proposed storage works on the Grand
river.
Attention has been given to propositions for flood prevention on the river
for many years, the Commission making certain surveys and investigations in
that connection some twenty years ago. The Department of Lands and Forests
requested the assistance of the Commission in a complete investigation of the
problems of alleviating flood damage, of maintenance of a higher flow in the
summer months, etc. A report, prepared jointly by the chief hydraulic engineer
of the Commission and the deputy minister of the Department proposed that
certain storage works be constructed, and investigated the effects of these in
reduction of flood peaks and in improvement of low water flows. Subsequently,
after submission of the report, the Legislature passed an act, known as the Grand
River Conservation Commission act, to provide the machinery whereby the
interested municipalities in the Grand River watershed might co-operate to
carry out the works or any desired part of them. During the past year, progress
has been made on further surveys, borings and examination of dam sites, and
on the preparation of plans, specifications and estimates for the initial storage
reservoir in the conservation scheme.
1934 HYDRO-ELECTRIC POWER COMMISSION 99
SECTION V
ELECTRICAL ENGINEERING AND CONSTRUCTION
(STATION SECTION)
NIAGARA SYSTEM
Generating and Switching Stations
Generating Stations on the Niagara River — The relaying system on
the 110, 000- volt lines at Queenston generating station is being improved and
definite-time relays were purchased and installed on each of the generator circuits.
MacLaren Development — The necessary engineering work was carried
out in co-operation with MacLaren-Quebec Power Company for the receipt of
the first block of 20,000 horsepower under contract for delivery on July 1, 1933.
Transformer and Distributing Stations
Niagara District — At Ontario Paper (Steam) transformer station, referred
to in last year's Annual Report as under construction, the transformers, electric
steam generators and all switching and controlling equipment were installed,
and were placed in service on February 2, 1933. Each of the three electric
steam generators is capable of generating 90,000 pounds of steam per hour and
is designed for a pressure of 200 pounds.
Temperature-measuring equipment indicates the hottest-spot temperature
in the transformers and permits safe loading of the transformers on a temperature
basis. In this way advantage may be taken of the low temperature of the
cooling-water in winter and the transformers overloaded in order to obtain more
steam during that season when it is required.
There are no high-voltage oil circuit-breakers at the transformer station.
In case of emergency the 110,000-volt line may be cleared by closing a solenoid-
operated, single-pole, ground-switch which effectively grounds the line causing
an oil circuit-breaker to open promptly at Queenston generating station. A
low-voltage oil circuit-breaker is located in each steam-generator circuit which
opens automatically to clear the respective feeder in case of ground or short-
circuit on a generator or feeder, and in case of failure of a circulating-pump
circuit.
In approximately four months from the time this work was started the
station was in service.
100 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
Late in October authority was given to proceed with the erection of a
transformer station including an electric steam generator at Provincial Paper
Limited plant at Thorold and another at Interlake Tissue Mills Company
Limited plant at Merritton. These stations when completed will enable the
respective companies to generate steam for their manufacturing processes and
in so doing put to beneficial use, under special contracts, a portion of the system
reserve power capacity at such times as it may be available.
There will be one three-phase, 7,500-kv-a. transformer and a 7,500-kw.
electric steam generator installed at each station. The generators have already
been purchased and the transformers and switching equipment will be purchased
in November, 1933.
The Thorold distributing station and Corbett distributing station on the
Dominion Power division were dismantled. Changes were made in the metering
equipment at Empire Cotton distributing station and at Page Hersey Tubes
Limited, Welland.
Hamilton and Dundas District — At Hamilton Beach transformer
station the relays on the 110,000-volt lines to Queenston generating station and
Toronto-Strachan and Dundas transformer stations were replaced by high-speed,
distance, directional, phase and ground relays and a fence was installed around
the lightning-arresters. Improvements were made to the fencing at Waterdown,
Hagersville, Decewsville and Lynden distributing stations and the electrical-
grounding system was changed.
Toronto and York District — At Toronto-Strachan transformer station
relaying equipment is being installed for differential protection on the 110,000-
volt bus, and high-speed selective relays on the high-voltage lines to Toronto-
Bridgman-Davenoort, Toronto-Wiltshire, Hamilton-Beach and Dundas trans-
former stations. Two 110,000-volt potential-transformers were transferred to
the station for this purpose. The current capacity of two of the 110,000-volt
line-entrances and part of the bus was increased.
At Toronto-Bridgman-Davenport transformer station the high-voltage
neutral was grounded through a water resistor and high-speed relays were
installed on the 110,000-volt line to Toronto-Strachan transformer station.
Changes were made in the 13,200-volt cable-connections.
At Toronto- Wiltshire transformer station improvements were made in the
metering and relaying equipment. High-speed relaying equipment was installed
on the line to Toronto-Strachan transformer station for which a new 110,000-volt
potential-transformer was purchased and installed.
At Toronto-Leaside transformer station improvements were made in the
relaying equipment and engineering work was carried on in preparation for
future installation of No. 7 and No. 8 transformer banks.
At Mount Joy and Sharon distributing stations changes were made to the
fencing and in the latter station the current-transformers were replaced by
larger-capacity units.
At New Toronto distributing station the 2, 300- volt disconnecting-switches
and lightning-arresters were replaced by more modern type units and improve-
ments were made to the outdoor bank of three 1,500-kv-a. transformers.
1934
HYDRO-ELECTRIC POWER COMMISSION
101
ELECTRIC STEAM GENERATORS
Two of three, 30,000-kw., 3-phase, 25-cycle, 6,600-volt steam generators for Ontario Paper
Company. Maximum operating pressure 200 lbs. per square inch
London District — Air filters and carbon-dioxide, fire-protection apparatus
were installed on the synchronous-condenser at London transformer station.
Improvements were made to the fencing and grounding system at Thames-
ford, Ailsa Craig, Glendale, Delaware, Broughdale, and Lucan distributing
stations. At the latter two stations necessary changes were also made in some
of the electrical equipment.
102 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
Guelph District — The graphic wattmeters at Acton distributing station
were replaced by more suitable type.
Preston District — Two original 110,000-volt oil circuit-breakers were
replaced by two of modern type transferred from Toronto-Bridgman-Davenport
transformer station.
Kitchener District — At Kitchener transformer station special thermal
instruments were installed on the Kitchener municipal feeders to enable the
total load to be read on meters situated in the municipal station.
Stratford District — At Stratford transformer station five inadequate
26,400-volt oil circuit-breakers were replaced. A new 450-ampere grounding
reactor for grounding the 26,400-volt bus was purchased and installed outdoors.
This reactor is used with the improved relaying system which was also recently
placed in service.
St. Marys District — At St. Marys transformer station one 110,000-volt
oil circuit-breaker was replaced by a modern unit transferred from Toronto-
Bridgman-Davenport transformer station.
Woodstock District — At Beachville distributing station the necessary
equipment for a second 13,200-volt feeder was purchased and installed.
St. Thomas District — The work under way at St. Thomas transformer
station last year was completed and placed in service.
At Aylmer distributing station a 4,000-volt switching structure was erected,
adjacent to the station, for sectionalizing the feeders to the various load centres.
Kent Transformer Station — At Bothwell distributing station improve-
ments were made to the fencing and grounding system.
St. Clair District — At Watford distributing station changes were made in
the meter connections and the graphic wattmeter was replaced.
At Arkona and Thedford the metering equipment was altered to meter
8.000-volt service instead of 4,000-volt service.
At Sarnia municipal station No. 2, air-break switches were purchased and
installed on the 26,400-volt line into the station and in the bus between No. 3
and No. 4 banks.
GEORGIAN BAY SYSTEM
Severn District — Extra accommodation was provided in the operators'
cottages at Big Chute generating station and improvements were made to the
sewage-disposal system..
Eugenia District — At Kincardine distributing station a bank of three
new 250-kv-a. transformers was purchased and installed replacing the original
bank of three 125-kv-a. units. The latter units were transferred to system
reserve.
At Shelburne distributing station improvements were made to the grounding
system, a 22,000-volt air-break switch was purchased and installed outside of
the station and metering equipment was installed on the Hornings Mills feeder.
At Owen Sound distributing station improvements were made to the grounding
system.
1934
HYDRO-ELECTRIC POWER COMMISSION
103
TRANSFORMER STATION— ONTARIO PAPER COMPANY
Outdoor layout of 110,000-volt station supplying current to
electric steam generators
Wasdells District — At Wasdells generating station water-connections
were made to the Superintendent's house and generating station and a sewage-
disposal plant was installed.
Muskoka District — At Gravenhurst distributing station improvements
were made to the station grounds.
Bala District — At Bala generating station a new structure was erected
opposite the present Bala generating station and the step-up transformers
feeding power to Port Carling and McTier were moved from their former situation
and installed on pads at the new structure, with the necessary switching equip-
ment. The original structure was dismantled.
KM TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
EASTERN ONTARIO SYSTEM
110,000-volt Transformer Stations — Telemetering equipment was pur-
chased and installed between Val Tetreau switching station and Ottawa trans-
former station, the meters being placed in the latter station. The installation
will give a graphic record of the total 110,000-volt, 60-cycle power received from
Gatineau Power Company.
Central Ontario District— A bank of three new current-transformers
was installed at Ranney Falls generating station and improvements were made
in the relaying system.
At Heely Falls generating station changes have been made in the installation
of the metering equipment.
At Brighton, Lakefield, and Cobourg distributing stations changes were
made in some of the metering equipment.
At Millbrook, Madoc, Belleville No. 1 and Warkworth distributing stations
and Belleville switching station improvements were made in the fencing of the
grounds.
At Oshawa distributing station the concrete walls of the original cooling-
pond were removed, the hole was filled in and the grounds were levelled to
conform with the adjacent grounds.
At Kingston distributing station a 1,500-kv-a., three-phase transformer was
installed, replacing a 750-kv-a. unit which was transferred to system reserve.
The current-transformers were correspondingly replaced by larger units.
At Kingston switching station the relaying equipment was improved.
St. Lawrence District — At Williamsburg distributing station a second
100-kv-a., single-phase transformer obtained from system reserve was installed
in parallel with the present transformer.
A new 225-kv-a. distributing station was installed at Maxville to supply
power to the town of Maxville and the rural power district. Three 40-kv-a.,
single-phase transformers originally at Omemee distributing station were rebuilt
for 75-kv-a. capacity and transferred to Maxville for this installation.
At Apple Hill distributing station, 4,000-volt metering equipment was
installed on the rural feeder supplying a portion of Maxville rural power district.
Rideau District — At the request of the Almonte Public Utilities Com-
mission, engineering assistance was given in the preparation of specifications
for, and in the purchase of a new 550-kv-a. generator for its hydro-electric plant.
THUNDER BAY SYSTEM
Transformer Stations — A step-up transformer station was installed
outside the Cameron Falls generating station for the purpose of delivering
power at 33, 000-volts to Northern Empire Mines Limited about 48 miles north-
easterly. Three 400-kv-a., 33,000/1 1,000- volt, single-phase transformers were
transferred from the Madawaska system and used for this installation with the
necessary switching, metering and controlling equipment. Power is supplied
from the 12, 000- volt bus in the generating station.
1934
HYDRO-ELECTRIC POWER COMMISSION
05
TRANSFORMER STATION AT CAMERON FALLS,
NIPIGON RIVER
At the Northern Empire Mines Limited station, metering equipment was
installed on the low-voltage feeders for metering the load supplied to this customer.
Engineering and other assistance at the request of the Northern Empire
Mines Limited was rendered the Company in the design and construction of its
step-down sub-station.
Port Arthur rural distributing station was installed near Port Arthur trans-
former station to supply single-phase, 6,600-volt power to the beach district
north-east of the city. A 75-kv-a. transformer obtained from Georgian Bay-
system reserve was used.
Fort William rural distributing station was installed to supply 8,000-volt,
three-phase power to Fort William rural power district from the 2, 300- volt
distribution lines. Three new 50-kv-a., 4,600/2,300-volt single-phase trans-
formers were purchased for the installation.
At Port Arthur rural distributing station, which supplies single-phase power
to the rural power district north of High street, a 37}^-kv-a., 2, 300/4, 600- volt,
106 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
single-phase transformer was purchased and installed in the feeder to permit
grounding it, and to isolate it from the ungrounded distributing system.
At Port Arthur transformer station high-speed relaying equipment was
installed on the 110, 000- volt and 22, 000- volt lines terminating at the station.
A rearrangement of the switching equipment was made on the three out-feed
110,000-volt lines.
At the Great Lakes Paper Company's plant at Fort William two electric
steam generators and 2, 300- volt switching, controlling and metering equipment
were installed and placed in operation under a contract with the company which
permits it to utilize reserve electric power capacity at such times as it may be
available, to generate steam required in its manufacturing processes. The
electric steam generators are each rated at 8,000 kw., 2,300 volts, and are suitable
for operation under 200 pounds steam working pressure. The Company is
using its own transformers to supply the power to the generators from the Com-
mission's 110,000-volt lines.
At the Provincial Paper, Limited, plant at Port Arthur a 24,000-kv-a.
transformer station is being installed for a similar purpose. Two 12,000-kv-a.,
60-cycle, three-phase, 110, 000/6, 600- volt transformers and two 12,000-kw.
electric steam generators have been purchased and will be installed and in
operation by the middle of November.
NORTHERN ONTARIO PROPERTIES
Abitibi District — The necessary generators, transformers and switching
equipment were installed and placed in operation at Abitibi Canyon development
to make available 55,000 horsepower as required for the customers on the system.
Studies and estimates were prepared in connection with the supply of
power to prospective customers. (See Frontispiece.)
Sudbury District — At Stinson generating station improvements were
made in the synchronizing, relaying and switching equipment.
At McVittie generating station, No. 1 generator was rebuilt with new
armature coils. Surge-absorbers were purchased and installed on the Burwash
feeder and improvements were made in the grounding system at the station.
At Coniston generating station improvements were made in the relaying
and grounding system.
At Sudbury distributing station a spare 1,000-kv-a., single-phase transformer
was purchased and installed. The 22,000-volt lightning-arrester was replaced
by a more suitable unit.
Manitoulin District — Kagawong distributing station was erected on the
site of Little Rapids Pulp Company's Kagawong development on Manitoulin
island to supply power to the Manitoulin rural power district at 11,400 volts.
Three 100-kv-a., single-phase, 60-cycle, 7, 200/600- volt transformers were
purchased for this installation.
ADMINISTRATION BUILDING
Tenders for the construction of an administration building were received
and a report thereon was prepared. The construction of the building however
was deferred by the Commission.
1934 HYDRO-ELECTRIC POWER COMMISSION 107
SECTION VI
TRANSMISSION, DISTRIBUTION AND RURAL SYSTEMS
TRANSMISSION SYSTEMS
The activities of the Commission's transmission section have been confined
largely to minor detail improvements within the various systems, and to con-
solidation and recording of extensive construction programs and of purchases
in previous years. Certain works of major importance were completed, notably
the extension of the 220,000-volt system to the Ottawa river at Cumberland,
where it connects with the line of the James MacLaren Company Limited from
the Masson development on the Lievre river, Quebec; the building of 48 miles
of 33, 000- volt line out of Cameron Falls transformer station, Nipigon river, to
serve the Northern Empire Mines Limited, and the serving of stations to generate
steam electrically.
The transmission system, recently purchased by the Commission, which
carries power from the Canyon development on the Abitibi river was taken
over and incorporated in the Northern Ontario properties.
Work has progressed in the reinforcement of telephone and railway crossings
in the various systems in conformity with the Board of Railway Commissioners'
regulations.
The following synopsis relates to the work undertaken during the year.
At the back of this report a map is included showing transmission lines and
stations and relative data are tabulated in Appendix II.
NIAGARA SYSTEM
220,000-volt Lines
Between a point on the Ottawa river opposite Masson and Cumberland
junction, a length of 1.33 miles of single-circuit, 220,000-volt, steel-tower line
was completed. This line is of similar construction to other 220,000-volt lines
of the Commission and was designed to transmit power from the Masson Power
Development of the James MacLaren Company Limited to the Niagara system.
110,000-volt Lines
Between a junction established at Holland road and the Ontario Paper
Company's plant at Thorold 0.66 mile of single-circuit 110,000-volt steel- tower
line was completed.
108 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
44,000-volt Lines
Between Burlington and Oakville, 10.9 miles, the former D. P. & T., single-
circuit, wood-pole line was removed, service to Oakville now being made over
the Commission's circuits reported in 1932.
26,400-volt Lines
Between Tilbury junction and Fletcher junction a portion of the 26,400-volt
circuit was removed from the telephone poles adjacent to the railway and placed
on a pole line which had been previously constructed on roads, for rural circuit
requirements. The revisions also included the relocation of switches and the
replacement of a small portion of steel cable with No. 2 steel-reinforced, aluminum
cable.
Rehabilitation of 5 sections of single-circuit, wood-pole line totalling 28.25
miles was completed in the vicinity of Dundas-Hagersville, Caledonia and
Decewsville. These lines had been in operation since 1912 and poles, cross arms,
etc., in most cases, were replaced.
Other Lines
At Brittania Junction two obsolete 13,200-volt air-break switches were
replaced by a modern type.
At Beachville distributing station the line entrance structure was rebuilt
and the line switching revised so that now two circuits enter the station.
The reinforcement of railway and telephone line crossings has been
continued.
GEORGIAN BAY SYSTEM
Eugenia District
Between Crombie junction and Orangeville distributing station 16.35 miles
of single-circuit, wood-pole line with telephone circuit were constructed. This
new line replaces the old which had become inadequate.
Severn and Wasdells Districts
Sixteen railway and telephone line crossings were reinforced in the Severn
and Wasdells Districts.
Work in these districts was confined to the reinforcement of crossings in
compliance with regulations of the Board of Railway Commissioners.
EASTERN ONTARIO SYSTEM
Between Dominionville junction and Maxville distributing station, 5.17
miles, the existing line which was originally built for 44,000 volts, but operated
at 4,000 volts was connected to the 44,000-volt circuit at Dominionville junction.
THUNDER BAY SYSTEM
Construction was completed of 48 miles of 33, 000-volt, wood-pole line
between Cameron Falls transformer station and the Beardmore mine. This
line is single-circuit with conductors of No. 4 solid copper.
1934
HYDRO-ELECTRIC POWER COMMISSION
109
*-7K
v .y t „-V*
3* t_
^
HYDRO 220,000-VOLT TRANSMISSION LINES
Transposition towers on the Beauharnois-Chats Falls line
Semi-anchor tower showing loop without
suspension insulator
HYDRO 220,000-VOLT TRANSMISSION LINES
BEAUHARNOIS-CHATS FALLS
Suspension tower with ten-foot extension
1J0 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
TELEPHONE LINES— ALL SYSTEMS
The telephone system of the recently purchased D. P. & T. Co. was
co-ordinated with that of the Niagara system. Approximately 17.5 miles of
single-circuit were erected to interconnect the two systems in the vicinity of
Hamilton, Decew Falls and St. Catharines.
In the vicinity of Effingham 1.40 miles of four-circuit, high-tension, telephone
line were diverted to a shorter route which eliminated extensive yearly tree
trimming.
DISTRIBUTION LINES AND SYSTEMS
In Appendix III is shown in tabular form the routine work carried on
during the year ended October 31, 1933, by the Distribution section of the
Electrical Engineering department.
Below is given a brief summary of some of the work undertaken by this
section in addition to the engineering activities required in connection with the
construction of new lines:
It is now twelve years since the first rural power districts were established.
While it is known that wood-pole lines in general have a life greater than this
period, in certain soils the decay in wood poles is very rapid. In addition, due
to growth in load and distance of transmission, the conductor sizes originally
installed become inadequate.
It should be noted also that before the present scheme of rural power districts
was originated, there were lines built to serve rural consumers by the Commission
and by the municipalities. These lines have practically all been incorporated
into the rural power districts. The time has now come when it is advantageous
to make a check of the physical condition of these old lines and also the adequacy
of the existing conductors to give satisfactory service with the present loads.
During the past year, the poles on some 75 miles of rural and distribution
feeder lines have been tested and recommendations made for the replacement
of about twenty per cent of these poles. In addition, voltage and load tests
were made in six rural power districts and recommendations made for the
improvement of conditions in these districts.
One item of improvement has been the installation of automatic booster
transformers at four locations. These automatic booster transformers are a
development of the past year.
While endeavouring to locate trouble on a privately owned underground
cable, a new method for finding faults on underground cable was developed.
This method was successfully used where other common methods of cable
testing failed owing to the nature of the fault. A current was passed through
the cable which was sufficient to warm the lead sheath which is used as a return
conductor. By exposing the cable at intervals and feeling the lead sheath with
the hand, the point of fault can be located by the lower temperature of the
sheath past the fault.
1934
HYDRO-ELECTRIC POWER COMMISSION
111
RURAL POWER DISTRICTS
GROWTH IN CAPITAL INVESTMENT -MILES OF LINE -NUMBER OF CONSUMERS
YEAR 1921 1922 1923 1924 1925 1926 1927 1928 1929 1930 1931 1932 1933 1934
DOLLARS
CAPITAL INVESTMENT
26,000,000
24.000,000
22,000,000
20,000,000
18.000,000
16. OOO, OOO
14.000.000
I2.000.000
IO. OOO. OOO
8,000,000
6.000.000
4.000,000
2.000,000
o
/'
/
/
^y
f
■
MILES
MILES OF PRIMARY LINE CONSTRUCTED
13, OOO
12 OOO
1 1. ooo
10,000
9,000
8.0
7,000
6 OOO
5. OOO
4.000
3,000
2, OOO
1. OOO
o
/'
NUMBER
NUMBER OF CONSUMERS
6 5,0 OO
6 O. O O O
5 5, O O O
5 O, O O O
4 5, OOO
40,000
3 5, OOO
3 0, OOO
25, OOO
20,000
1 5, OOO
IO, OOO
5. OOO
O
y
/
/
/
/
,/
VEAR 1921 1922 1923 1924 1925 1926 1927 1928 1929 1930 1931 1932 1933 1934
112 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
The work of ground connection improvement has been continued during
the past year. To date, tests have been made on the resistance of some 23,000
grounds in 160 rural power districts. Specifications for the necessary improve-
ment have been issued in 68 rural power districts in which there are approximately
13,000 ground connections. In the above 160 rural power districts, about
14,000 ground connections now meet the standard of 25 ohms or less.
Weekly tests were made during the year on the resistance of the ground
terminals at the four test stations installed near Toronto. It is proposed to
carry on these tests during the winter of 1933-34 in order to obtain more complete
records of the effect of frost on the ground terminal resistance.
The results of the past years tests are now being analyzed. Upon completion
of this analysis, a report of the results obtained will be issued.
1934 HYDRO-ELECTRIC POWER COMMISSION 113
SECTION VII
TESTING— RESEARCH— INSPECTION
The Testing and Inspection department has three main divisions — the
Testing and Research laboratories, the Approvals laboratory, and the Electrical
Inspection division.
The division of the department known as the Testing and Research labora-
tories comprises the Electrical laboratory, Engineering Materials laboratory,
Chemical laboratory, Illumination laboratory, and the Photographic and
Blueprint b ranches. This division supplies a testing, research and materials-
inspection service to the other departments of the Commission and to the Muni-
cipalities embraced in the Commission's operations. Its staff is composed of
engineers, chemists and laboratory assistants who carry out their duties in the
laboratories or in the field, as expediency or necessity may dictate. The
Approvals laboratory is charged with the duty of administering the rules and
regulations of the Commission governing electrical equipment. It is composed
of a staff of laboratory engineers and factory inspectors; the former are engaged
almost entirely in making laboratory tests and the latter in making inspections
in the factories and in the field. The Electrical Inspection division is responsible
for the administration of the Rules and Regulations of the Commission governing
electrical installations. It is organized in districts covering the entire Province,
in each of which one or more inspectors are stationed. The work of this division
involves inspection, but this is quite different to the inspection carried on by the
Testing and Research laboratories. The latter inspects materials and equipment
which the Commission purchases for its own use while the former is charged
with the duty of inspecting wiring installations in houses, offices, etc. and indus-
trial installations in order to determine whether or not such installations contain
a fire or a shock hazard.
An event of importance in the year's operations was the formation of a
Research committee in the Commission. The objects of this committee are:
to correlate the investigational work of all departments, to discover and develop
research talent in the Commission, to encourage the staff to submit ideas which
may be developed for the benefit of the Commission and to guide research work
in the Commission. The main Research committee consists of five department
heads. Sub-committees are appointed to undertake specific research under the
direction of the main committee. Nine projects are now active and encouraging
progress has been made. Reference is made below to several of these projects.
H4 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
TESTING AND RESEARCH LABORATORIES
Statistical and Routine Work
During the year, 40,784 tests of all classes were made in this division of
the department. Of this total the Electrical laboratory made 15,734 tests, the
Chemical laboratory 1,195, the Structural Materials laboratory 4,097, and the
Photometric laboratory 19,758. The Blueprint branch completed 3,778 orders
and made 48,171 prints having a total area of 121,679 square feet, and the
Photographic branch completed 551 orders covering all phases of dark room,
studio and field photography. These statistics cover testing to assure the
standard of quality of items such as insulating oil, transmission line hardware,
rubber gloves, oils and paints, wire and cable, concrete materials and luminous
lighting devices as well as special tests involved in miscellaneous investigations
and research.
Although this particular phase of the laboratory activities does not change
materially from year to year, the work is continually becoming more diversified
and the laboratory is called upon to develop new methods and equipment for
routine or special testing. An example of this is the new section recently estab-
lished for conducting physical and chemical tests on insulated wire conductors
and electrical conduit and tubing.
Materials and Equipment Inspection Work
The volume of general inspection work was considerably reduced this year
owing to the continued depression in the construction activities of the Com-
mission.
Transmission Line Materials
The routine inspection of transmission line materials was of the same general
character as in previous years. All articles such as bolts, cross-arms, pins,
splices, connectors, brackets, galvanized steel wire, copper and aluminum con-
ductors and tower-line steel are subjected to rigid inspection either at the
laboratory or in the manufacturers' shops. Faulty materials are thus eliminated
and hazards to human life as well as service interruptions due to line failures
are minimized.
Equipment
The principal items inspected during the period covered by this report were
44 transformers of total capacity 221,805 kv-a and equipment required in the
construction of seven electric steam generators having a total capacity of 130,000
kw. During the fabrication of boiler steel for these generators a resident
inspector was stationed at the plant, and witness tests were made on the assembled
units before final acceptance was granted. Particular attention was also given
to the welding of equipment for these installations.
Preliminary work has been done on the inspection of equipment required to
complete the Beauharnois contract. This will include the inspection of
turbines, generators, governors, circuit breakers and transformers used to supply
power to the Commission.
1934
HYDRO-ELECTRIC POWER COMMISSION
15
FIELD INSPECTION OF CONCRETE STRUCTURES
Where conditions warrant, affected areas are outlined on the structure and photographed so
that the rate of deterioration may be followed annually
Concrete
Inspection of the Commission's concrete structures as a means of detecting
incipient deterioration has been continued. These inspections also afford an
opportunity for the laboratory staff to observe the durability of various building
materials in service and they assist in making recommendations as to the most
suitable materials for the Commission's use. Inspections of this character
during the year included eight plants in the Georgian Bay district, three plants
in the Nipissing district, three plants in the Sudbury district, the canal walls at
Queenston, the generating station and main dam at Eugenia, and the two plants
on the Nipigon river.
Although no major concrete construction has been carried out during the
year, the inspection staff has assisted in making recommendations as to materials
and mixtures for repair work and minor jobs, and has also compiled detailed
records on the recently completed construction at Chats Falls and Abitibi Canyon.
Research
Mew Methods and Materials
An important function of the testing and research division is to investigate
the merits of new methods or materials and to report upon their usefulness or
suitability in the Commission's maintenance and construction work. Items of
this nature investigated during the year include cork insulations for preventing
condensation on pipes; special devices for transmission line construction; paints
for specialized purposes; spray equipment for creosoting poles; roofing materials
for powerhouse use; heaters, thermostats and boiler lagging for domestic hot-
water service; hardware for low- voltage lines, and insulating cements for electric
steam generators.
H6 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
Investigation of Troubles
The laboratories are frequently requested to investigate troubles which
occur in operation and to report upon remedial measures which will prevent
their reoccurrence. The following are typical examples of this type of service:
Recommendations were made for treating cooling-pond water to
prevent the formation of pipe scale.
A metallurgical examination of a broken tower member revealed that
segregation in the steel had caused the failure.
Defective turbine runner bolts at Queenston. Microscopic examination
revealed segregation of the metal and the replacement of these bolts was
advised.
Defective set screws from bearings at Queenston. Hardness and
brittleness had caused failure through impact. Properly heat-treated set
screws were recommended.
Galvanizing which had turned black in service. This investigation is
still in progress.
Ground wire and dead-end clamps replaced in the field after several
years' service were examined to determine any condition which would assist
in making these replacements less frequent.
Investigations Leading to Improvements in Methods or Materials
The following problems have received attention during the year:
Comparative tests on bare welding rod and covered rod. In all cases
the covered rod was found to be superior.
Investigation of the physical characteristics of aluminum strands in
steel-reinforced aluminum conductors, particularly in regard to their bending
qualities. The tests showed lack of uniformity in this respect.
Study of a special line fault indicator. Sufficient time has not elapsed
to warrant comment upon its merits.
Development of an electrical stress-strain instrument for recording
vibration in transmission line conductors. This promises to be a very
useful piece of apparatus.
Treatment of concrete walls where moisture presents a serious obstacle
to painting. Several treatments have been investigated.
Plastic insulating cement for covering joints in large electrical con-
ductors. A satisfactory cement was found.
Selection of a suitable cement filler for slate panels.
Development of a new method of stubbing wood poles to prevent
rotting at the ground line. Assistance was given our engineers at the
laboratory and in the field.
Water heating installations for domestic hot-water service. Many
special tests were made to investigate the merits of equipment and types of
assembly. A large amount of valuable practical data has been obtained
and considerable assistance was afforded the manufacturers in developing
suitable equipment.
1934
HYDRO-ELECTRIC POWER COMMISSION
117
APPARATUS FOR MEASURING THE GLOSS OF PAINTS
Illumination Laboratory
Treatment of Wood Poles
The extent of the Commission's rural transmission lines has warranted a
thorough investigation as to the efficiency of various kinds of preservative
treatments. Considerable progress has been made in the study of this problem.
Annual inspections of the Barrie test bed are being made and the installation of a
second test bed near Donlands has been completed. Twenty-four soils from the
Niagara district were tested, and over 400 poles from various localities were
inspected and recorded for future study. A special device for creosoting poles
already in service was investigated, and data pertaining to the history of certain
selected pole lines were studied.
Paint
The testing and inspection of paint is one of the most valuable services
rendered by the Chemical laboratory. This laboratory not only makes routine
tests on paints regularly purchased by the Commission, but is constantly investi-
gating the merits of new products and making recommendations where paints
for special purposes are requested. It continues to co-operate in making
laboratory tests and field inspections of tower line painting. This service has
resulted in a substantial saving in maintenance charges.
Recent developments in paint testing include : microscopic examination of
specimens to detect initial failure and photometric measurements for gloss,
where this feature is of importance.
H8 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
Concrete
Concrete problems investigated during the year have included :
Comparative tests on standard silica sands for cement testing. These
tests were made in co-operation with the Canadian Engineering Standards
Association with a view to adopting a Canadian sand if it proved satisfactory.
Tests on standard aggregates for major concrete investigations. These
tests were necessary as the materials formerly used as standard are no
longer available. New materials were selected and tests were made to
correlate our porportioning data.
The grouting of joints which have given trouble in our existing concrete
structures. Cement and asphalt materials were investigated and recom-
mendations were made for the repair work at Nipigon.
The study of problems relating to winter concreting. Placing of
concrete during freezing weather presents many specific problems worthy
of special consideration. An investigation is now in progress to study the
thermal characteristics of concrete and concrete aggregates, the capacity
of heating plant necessary for given temperature conditions, the heat
generated by chemical reactions in freshly-set concrete and the curing
temperatures necessary to provide economical yet adequate curing protection.
The use of crushed limestone or granite as a substitute for natural
sands. Proportioning tests for this study are now being made and over
500 cylinders out of a total of 790 have been completed.
Preliminary work done last year on an analysis of the variations in
concrete strength tests has been continued. A comprehensive survey of
Hydro and foreign field data was made to assist in revising the present
concrete strength classifications.
The resurfacing and patching of deteriorated concrete. Field tests
have been made using various treatments on sidewalks.
Typical defects which occur due to faulty design or construction have
been photographed for the information of our engineers.
Insulating Oils
A major investigation is now being made to determine the feasibility of
reconditioning insulating oil in large quantities. Apparatus of sufficient capacity
to reclaim oil on a modified commercial basis has been assembled at the laboratory
and the results of tests have been very encouraging. Some mechanical difficulties
were experienced, but it is expected that satisfactory field equipment will be
developed for restoring deteriorated oil to many additional years of service.
Other studies in respect to insulating oil have been the investigation of
operating temperatures as they affect the rate of deterioration, a survey to
determine the condition of insulating oils in service and an investigation to
establish a more sensitive test for sludge determination.
Radio Interference
The laboratories continue to co-operate with the Dominion Department of
Marine in efforts to eliminate radio interference caused by apparatus on electrical
1934
HYDRO-ELECTRIC POWER COMMISSION
119
ENDURANCE TEST ON THERMOSTATS
Approvals Laboratory
systems. The chief sources of this trouble are transformers, lightning arresters,
fused outlets, insulators and some types of line hardware. Power companies
are giving an increasing amount of attention to this matter.
Oscillographic Studies
Special tests on a rather extensive scale have been made using oscillograph
elements where the time involved was of short duration. These instruments
are particularly flexible and they may be used to record any mechanical quantity
which may be duplicated by its electrical equivalent.
Vibration of Transmission Line Conductors
During the year the facilities of the laboratory were involved to a greater
extent than heretofore in the study of vibrations in transmission line conductors.
Several methods of attacking this problem have been investigated, and special
electrical apparatus for measuring the vibrations has been developed. Very
satisfactory progress has been made and it is expected that these studies will be
continued.
20
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
LABORATORY FOR TESTING INSULATED WIRE CONDUCTORS
A low-temperature refrigerator is shown at the left, the tension and recovery machine in the
centre foreground and the cord endurance tester in the centre background
Communication
Communication problems are continuous in character but new aspects are
constantly presenting themselves, particularly those in respect to carrier wave.
The merits of several new systems have been studied.
Industrial Research
Assistance has been given in co-operation with the Department of Industrial
Research, University of Toronto, in problems relating to resuscitation from
electric shock and the prevention of silicosis. A member of the laboratory staff
has been assigned to assist in the development and control of electrical apparatus
used in the investigation of these important humanitarian problems.
Miscellaneous
New Equipment
The only new equipment added during the year was that required in the
establishment of a new section for testing insulated wire conductors and electrical
tubing and conduit. As far as possible the equipment already in the laboratory
was adapted to the new work, and only such apparatus as could not be assembled
in our own shops was purchased. New equipment purchased for this work
includes an electric refrigerator capable of attaining a temperature of -22° Fahr.
and a Pyrofax gas machine for conducting flame tests. Both of these items may
be used for a multiplicity of purposes in general laboratory work.
934
HYDRO-ELECTRIC POWER COMMISSION
21
BRAKE TESTS ON SMALL MOTORS
Approvals Laboratory
TEMPERATURE AND OVERLOAD TESTS ON FUSES
Approvals Laboratory
L22 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
It was also necessary to purchase or construct for use in the laboratory
several machines for physical testing of rubber and other insulating materials.
These included a special refrigerator, machines for buffing rubber and stretching
wire, impact testing, testing tensile strength of armoured cable and other cable,
tightness of armour, abrasion of insulation and endurance of heater cords. It
was also necessary to purchase a considerable number of small tools, micrometers,
balances, gauges, dies, thermometers, etc. for bench work on these materials.
To take care of life tests on thermostatically-operated controls for refrigera-
tors and water heaters a special set-up was devised so that streams of hot and
cold air alternately could be passed over the device at varying rates. Several
new jigs were constructed for switch and socket tests, together with a device for
applying heat so that heater switches could be operated at normal temperature.
A 12-point pyrometer for measuring temperatures by means of thermocouples
on automatic irons, toasters, percolators, etc. was adapted for use in the investi-
gation of these appliances.
A reactor coil was designed and constructed to furnish a load for testing
switches for the control of single-phase motors. With this coil it is possible to
obtain loads equivalent to locked-rotor loads of motors in capacities from 1/6 to
2 h.p. at 115 volts and from 1 to 5 h.p. at 230 volts.
Standardization
The standardization activities of the department have on the whole been
maintained at approximately the same level as last year. The preparation of
specifications under Part II of the Canadian Electrical Code has been pressed
vigorously forward, as noted in the report of the Approvals laboratory. The
benefits of this work both to the Approvals laboratory and the manufacturers
are continually evident.
As mentioned in the last report, the Approvals laboratory on January 1, 1933,
undertook the inspection of wire, cable, conduit and other items formerly under
the inspection service of Underwriters' Laboratories. This work is carried on
in co-operation with the Canadian manufacturers and the Canadian Engineering
Standards Association under the standards of the Canadian Electrical Code.
Lighting Service
This service is provided for the use of the municipalities and their customers.
During the year twelve reports were submitted in response to requests for
lighting plans.
Lamps
The Photometric laboratory continues to conduct tests on and to make
inspections of all Hydro lamps sold throughout the Province. Samples for
life tests are selected from each batch of lamps manufactured for the Commission.
The tests of these reveal the inherent quality of the lamps and serve to show
whether or not they comply with the requirements of the Commission's specifica-
tions. The accumulated information also furnishes a basis for improvements
in efficiency as experience dictates.
1934 HYDRO-ELECTRIC POWER COMMISSION [23
APPROVALS LABORATORY
Statistical
The following table contains a summary of the testing and inspection work
of the Approvals laboratory for the past two years:
1932 1933
Applications for approval 660 743
Special approval tests, etc 178 237
Listing 52 67
Factory inspection reports 3,039 3,328
Labels sold— (16 types) 696,100 621,723
Conduit 446,000
Wire, cord, etc 334,000
Applications for approval :
Motor-driven appliances 222
Electrically-heated appliances 168
Wiring devices 125
Lighting devices . . . 106
Industrial control and transformers 43
Miscellaneous 43
Wire and cable. 19
Radio and sound 17
Summary of Work
Specifications
Specifications in process by Canadian Engineering Standards
Association, November 1, 1932 15
Specifications printed since November 1, 1932 5
Specifications advanced to final C.E.S.A. form 4
Specifications begun during year 10
(Some advanced to C.E.S.A. draft form and others still in
laboratory draft.)
Meetings of C.E.S.A. Specification Panel attended 15
Average attendance of laboratory engineers 3.5
Other meetings attended relating to Approvals work 3
One engineer is devoting his whole time to specifications. Two others are
giving part time and several others are consulted as required in order to insure
that all requirements are properly covered by any draft.
In addition to this work some standardization work has been done in con-
nection with the marking of plug fuses and of mercury contact switches. Several
bulletins were also issued referring to appliance plugs, use of flexible cords,
cartridge enclosed fuses, and insulated wires and cables. By arrangement with
Canadian Engineering Standards Association these bulletins were circulated
by that association to manufacturers and others concerned.
24
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
ENDURANCE TEST ON THREE-HEAT RANGE SWITCHES
This test is being made at constant temperature of 100 deg. C.
Approvals Laboratory
The Safety Code for elevator equipment proposed by the Canadian Engineer-
ing Standards Association was reviewed and an appendix covering electrical
features for inclusion in this code was compiled.
Other specifications received through the Canadian Engineering Standards
Association from the British Standards Institution and the Australian Standardiz-
ation Association have also been reviewed and comments forwarded.
Label Sales
Commenting on the summary of labels sold, as compared with the previous
year, there is a drop of approximately 75,000 or about 11 per cent. This
loss of revenue was more than made up by the sale of labels for conduit, fixtures,
insulated wire and cord, heater cord, armoured and non-metallic sheathed cable,
flexible steel conduit and non-metallic tubing. The continued general depression
in the building trades however kept the demand for this label service to a low
point as it did not come up to the estimate.
To handle the inspection required by an increasing number of label users
in the district surrounding Montreal, it was found necessary to open a branch
1934 HYDRO-ELECTRIC POWER COMMISSION [25
office in Montreal where laboratory specifications and other information could
be available as well as labels. This arrangement has worked out very well.
In the Western Provinces, the business depression has probably been more
acutely felt by manufacturers with the result that the falling off in demand for
label service has been more pronounced than in Ontario and Quebec.
A revised list of approved electrical equipment will be issued early in 1934.
Field Sales Control
During the year twenty-two offenders were brought to Police Court for
breach of Rule 103 and many more were served, or about to be served, with
summons but further action was dropped when compliance with the Regulations
was forthcoming. Of the above number six were fined.
An attempt was made by one concern to bring in substandard Christmas
tree sets and incandescent lamps. Much time was taken up and several court
cases resulted both in Toronto and surrounding towns before the further distri-
bution of these sets was checked. The use of assumed names by the offenders
made it difficult to cope with this class of offender.
ELECTRICAL INSPECTION DEPARTMENT
The Electrical Inspection department of the Hydro-Electric Power Com-
mission has now been in operation for a period of eighteen years. It was formed,
in the latter part of 1915, to supervise the carrying out of the Rules and Regula-
tions governing electrical installations in all municipalities of the Province of
Ontario. It functions for the Provincial Government under the direction of
the Hydro- Electric Power Commission.
While the work of the Department varies but little from year to year, the
volume handled is governed, to a large extent, by the amount of new building
construction carried on throughout the Province. The value of this has shown
a steady decline from $116,203,200 in 1930 to $26,292,000 in 1933.
There are reasons for believing that the bottom of the depression has been
reached, so far as building construction statistics, covering a period of years,
would indicate. The number of paid applications, for inspection, received in
1933, amounted to 75,054, a decrease of 1,117 or 1.47 per cent from 1932.
The small decrease in the number of permits issued does not however accord
with the building construction situation, outlined above. The number of
permits was maintained at a higher level as a result of the Commission's water
heater campaign. If this field of work had not been created, the number of
permits issued would have fallen off by approximately 15 per cent.
In all, 137,760 inspections were made, a decrease of 16,135 or 12 per cent
from 1932.
The accompanying graph shows the monthly trend of permits issued,
inspections made and the cost of building construction in Ontario for the period
1930 to 1933.
126
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
NUMBER OF «. VALUE OF
INSPECTIONS MADE BUILDING
PERMITS ISSUED CONTRACTS LET
isIUi5l§s§alisinii§S5§8lislSi8i§55i8lssIliliia5§§|jSllIiisSsi:
30.000
25.000
$15,000,000
$10,000,000
$ 5,000,000
1930
1931
1932
1933
NOTE— Curve A = No. of inspections; Curve B = No. of permits issued
Curve C = Value of building contracts
Fires
Of the numerous fires reported to the Department as having been caused
by defective electric wiring, investigation has definitely placed the causes of
31 as due to defective wiring. This number is an increase of 11 over last year.
The fires are classified, as to origin, below:
Armoured cable 4
Wires overfused 5
Heaters (improperly used) 3
Defective joints 2
Short circuits 5
Lamp in barn, covered with chaff,
as a result of threshing operations 1
Flexible cord 6
Service conduit blowout 1
Iron left on 1
Motors 3
Total 31
1934 HYDRO-ELECTRIC POWER COMMISSION [27
Electrocution
During each year, a number of instances of electrocution are reported, in
the- newspapers, throughout the Province. Most of these are brought about
by persons coming into contact with high-voltage wiring and equipment which
is not under the jurisdiction of the Inspection Department.
Four fatal accidents occurred, within the past fiscal year, through equipment
under the jurisdiction of this Department. The individual causes are cited
below :
Man electrocuted by coming into contact with an amusement device,
on which an intermittent ground existed. Voltage of circuit, 110.
Man electrocuted while making alterations to a heater connection;
neglected to pull switch. Voltage of circuit, 550.
Man electrocuted while working with an electric jack which was not
grounded. Voltage of circuit, 550.
Man electrocuted while painting pipe framework around switching
equipment. Voltage of circuit, 2,200.
Two cows and one horse were also electrocuted. High resistance
grounds were the cause in each instance.
Infractions of Regulations
Forty-two persons and companies were prosecuted for various infractions of
the Rules and Regulations. Fines amounting to $480 and a number of suspended
sentences were imposed.
The routine work of inspecting the older and more obsolete type of installa-
tion has been carried on as in previous years. Owing to present conditions, more
time and effort is required to influence the consumer to have the installation
brought up to a reasonable standard of safety than was formerly the case. The
Department has recognized the hardships which might be imposed, in this
connection, and has only taken action where life and fire hazard exist. In all,
2,603 installations were brought up to a reasonable safe condition at an approxi-
mate cost of $138,848.
Artificial Grounds
This year, 2,222 artificial grounds were tested as compared with 3,824 last
year. The readings obtained give the Department a knowledge of the ground
protection on each installation before the supply lines are connected. This
information, along with other data, is turned over to the Engineering department,
for study, with a view to improving upon the types of artificial grounds now in use.
128 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
SECTION VIII
ELECTRIC RAILWAYS
THE SANDWICH, WINDSOR AND AMHERSTBURG
RAILWAY COMPANY
Operation
In 1933 the gross earnings were $492,795 as compared with $568,452 in
1932, a decrease of $75,657. The 1933 operating expenses were $498,134 as
compared with $564,692 in 1932, a decrease of $66,558. There was an operating
deficit of $5,340 as compared with an operating net of $3,759 in 1932.
The adjustment of the 1932 power bill was made too late to be included in
the 1932 report and the amount — $4,872 has been credited to 1933 operating
expenses. Similarly, the 1933 adjustment has not been made at this writing.
Industrial conditions in the Border Cities show little or no change for the
better and the earnings of the Railway decreased 13 per cent while operating
expenses have been reduced 11.7 per cent.
The accompanying chart indicates the record of the Railway for the past
five years.
The mileage operated by the various types of cars during the year is as
follows: — double truck, air brake, two-man cars 2,823 car-miles; interurban
cars, 438,297 car-miles; single truck safety cars, 569,528 car-miles; double truck
safety cars, 1,311,334 car-miles; express cars 10,944 car-miles; service cars,
12,268 car-miles; total 2,345,194 car-miles.
934
HYDRO-ELECTRIC POWER COMMISSION
129
SANDWICH, WINDSOR AND AMHERSTBURG RAILWAY
OPERATING STATISTICS
GROSS REVENUE
5 ZOO, 000
------ -_
= ---"
"_-
TOTAL EXPENSES
> zoo.oou
100,000
—
— - -_- .
- ■ - — - -
•
NET OPERATING REVENUE EXCLUDING TAXES
540,000
" "" -■--.
'
10 000
-
PASSENGER REVENUE
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PASSENGER CAR MILES
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1930
1931
1932
1933
130 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
SANDWICH, WINDSOR AND AMHERSTBURG RAILWAY
Operating Statistics, 1933
Route-miles: —
City 24 . 81
Amherstburg interurban 13 . 54
Tecumseh interurban 5 . 34
Total route-miles 43 . 69
Passenger and freight car-miles operated 2,332,926
Passenger and freight car-hours operated 237,426
Passengers carried 8,576,698
Percentage of transfer passengers to revenue passengers 21 . 15 %
Passenger cars operated 58
Passengers carried per route-mile 196,308
Passengers carried per car-mile 3.7
Passengers carried per car-hour 36.4
Average mileage per car operated 40,031
Average passengers per car operated 147,874
Freight tonnage carried 1,616
Accidents 315, of which 214 were automobile accidents.
Accidents per 100,000 car-miles: 12.698.
GUELPH DISTRICT RAILWAY
Operation
The operating revenue for the Guelph District Railways for 1933 was
$57,455 as compared with $65,595 in 1932. The operating expenses for the year
1933 were $69,806 as compared with $73,380 in 1932. The net operating shortage
was $12,351, as compared with $7,784 in 1932. The interest and debenture
payments were $25,468 as compared with $25,588 in 1932. Sinking Fund
requirements were $3,15-9 as compared with $3,159 in 1932. Nothing was set
aside for renewals. The deficit for 1933 was $41,332 as compared with $36,885
in 1932.
Included in the above deficit is $8,351, which had been set aside for
amortizing the original value of the Railway previous to the transfer of this
road to the Hydro-Electric Power Commission; and also an interest charge of
$3,349.
The freight earnings for the year 1933 were $8,931 as compared with $10,506 .
Passenger earnings were $47,921 in 1933 as compared with $54,373 in 1932.
934
HYDRO-ELECTRIC POWER COMMISSION
131
GUELPH DISTRICT RAILWAYS— OPERATING STATISTICS
GROSS \
REVENUE
% 20.000
""- - ~-~ -~ _ -«-
~ —
----- ---_
TOTAL E
XPENSES
) 10,000
10,000 ~j~
--~-L ~ - — " --_ --_
- - - _
NET OPERATING REVEr
1UE EXCLUDING TAXES
$ 3,000 " |
_
"
1 ,000 _ _ _
™" _ —
~~_~ - -- -
_
— _ **
""— — ~ —
_ _
PASSENGEF
I REVENUE
-_ -
— -" — - --J-__ — *"---_
F-__ — — ~ — — — —
o — *— =
PASSENGER
CAR MILES
.
J_
"
- ----""----" -_------ -_-_
"---_.-- -_----_-
q 1 1 II 1 1 1 1 1 1 1 1 1 t 1 L.
zo?<£izj0o.i->u zmjo:>zjoai->u z • 5 f } z
?rJij???S!i?g 5 If 1 i s 5 3 3 S o i o ^lii^
AUG
SEPT
OCT
NOV
FEB
APR
JUNE
JULY
AUG
SEPT
OCT
NOV
DEC
JAN
FEB
APR
JUNE
AUG
SEPT
OCT
NOV
DEC
1930
1931
1932
1933
Ybl TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
GUELPH DISTRICT RAILWAY
Operating Statistics, 1933
Route-miles: —
Trolley 6.41
Bus 5 .99
Total route-miles 1 2 . 40
Track-m iles 9.06
Passenger cars operated 7
Buses operated 4
Passenger car-miles operated 221,185
Bus-miles operated 91,419
Freight-locomotive-miles 9,908
Passenger car-hours operated 27,619
Passenger bus-hours operated 13,037
Revenue passengers carried 835,867
Transfer passengers carried 226,996
Free passengers carried 3,402
Total passengers carried 1,066,285
Percentage of transfer passengers to revenue passengers 27 . 1
Freight motor cars operated 1
Freight motor-hours operated 2,141
Total passenger freight and service car-miles operated 332,536
Accidents: — 17 of which 11 were due to automobiles.
Accidents per 100,000 car-miles— 1927, 8.24; 1928, 4.25; 1929, 12.3; 1930, 7.2; 1931, 4.45;
1932, 5.95; 1933, 5.1.
934 HYDRO-ELECTRIC POWER COMMISSION 133
SECTION IX
FINANCIAL STATEMENTS
Relating to Properties Operated by The Hydro -Electric Power
Commission on Behalf of Municipalities
The following explanatory statement is submitted with a view to affording
a satisfactory understanding of the manner in which the various operations of
the Hydro-Electric Power Commission of Ontario are conducted and financed
and thus contributing to the interest of those concerned either directly or
indirectly with the Work of the Commission.
The "Hydro" electrical undertaking of Ontario is an organization of a large
number of partner municipalities co-ordinated into groups or systems for securing
common action with respect to power supplies, through the medium of the
Hydro-Electric Power Commission which under the Power Commission Act
functions as their trustee. The undertaking as a whole, embracing all the
operations from the provision of the power down to its final delivery to the
ultimate consumer, involves two distinct phases of operations.
The first phase of operations is the provision of the electrical power — either
by generation or purchase — and its transformation, transmission and delivery
in wholesale quantities to individual municipal utilities, to large industrial
consumers, and to rural power districts. This phase of the operations is
performed by the Hydro-Electric Power Commission of Ontario as trustee for
the municipalities acting collectively in groups or "systems," and the financial
statements relating to these collective activities of the municipalities are
presented in this section of the Annual Report.
The second phase of operations is the retail distribution of electrical energy
to consumers within the limits of the areas served by the various municipal
utilities and rural power districts. In the case of rural power districts, which
usually embrace within their confines portions of more than one township, the
Hydro-Electric Power Commission not only provides the power at wholesale, but
also — on behalf of the respective individual townships — attends to all physical
and financial operations connected with the distribution of energy at retail to
the consumers within the rural power districts.* The financial statements
relating to the rural power districts are also presented in this section of the
report. In the case of cities, towns, many villages and certain thickly populated
areas of townships, retail distribution of electrical energy provided by the
Commission is in general conducted by individual local municipal utility com-
*For further information respecting rural power districts consult latter portion of Section
III in this Report.
134 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
missions under the general supervision of the Hydro-Electric Power Commission
of Ontario. The balance sheets, operating reports and statistical data relating
to such individual electrical utilities are presented in Section X of this report.
Having the foregoing distinctions respecting wholesale and retail electrical
service in mind, the following brief notes will assist to an understanding of the
economic structure and of the general plan of administration of the undertaking,
and will make clearer the financial tables herein presented. The basic principle
governing the financial operations of the undertaking is that electrical service
be given by the Commission to the municipalities and by the municipalities to
the ultimate consumers at cost.
The charges for power supplied by the Commission to the various
municipalities vary with the amounts of power used, the distances from the
sources of supply and other factors. The entire capital cost of the various power
developments and transmission systems is annually allocated to the connected
municipalities and other wholesale power consumers, according to the relative
use made of the lines and equipment. Each municipality assumes responsibility
for that portion of property employed in providing and transmitting power for
its use, together with such expenses — including the cost of purchased power if
any — as are incidental to the provision and delivery of its wholesale power. The
entire annual expenses — including appropriations for reserves — incurred by the
Commission in the supply of power at wholesale are thus paid out of revenues
collected in respect of such power, through the medium of power bills rendered
by the Commission. The municipalities are billed at an estimated interim rate
each month during the year and credit or debtit adjustment is made at the end of
the year,* when the Commission's books are closed and the actual cost payable
by each municipality for power received has been determined.
Included in the municipality's remittance to the Commission for the
wholesale cost of power — besides such direct expenses as those for operation
and maintenance of plant, for administration, and for interest on capital — are
sums required to build up reserves for sinking fund, for renewals, and for
obsolescence and contingencies. The first-mentioned reserve is for the purpose
of liquidating the capital liabilites; consequently, as capital obligations are
discharged the plant will progressively be freed from interest expense. The
other reserves are, respectively, being created to provide funds for the replacing
or rebuilding of plant as it wears out; to enable the undertaking to replace
existing equipment with improved equipment as it becomes available through
advances in science and invention, and to meet unforeseen expenses which from
time to time may arise.
The ultimate source of all revenue to meet costs — whether for the larger
operations of the Hydro-Electric Power Commission or for the smaller local
operations of the municipalities — is, of course, the consumer. Out of the total
revenue collected by each municipal utility from its consumers for service
supplied, only an amount sufficient to pay the wholesale cost of power supplied
by the Commission as outlined above is remitted to the Commission; the balance
of municipal electrical revenue is retained to pay for the expense incurred by
the local utility in distributing the electrical energy to its consumers.
*The financial year for the Commission ends on October 31. The financial year for the
municipal electric utilities, however, ends on December 31, and the municipal accounts are
made up to this date, and so recorded in Section X.
1934 HYDRO-ELECTRIC POWER COMMISSION [35
The results obtained by the annual adjustments of the Commission's
capital investment, operating expenses and fixed charges, as they affect individual
municipalities are shown in the tables for the respective systems. For the purpose
of financial statement, the various systems are treated as separate units and for
each of them similar statements and details are presented. Many of the pages
which follow, therefore, simply repeat for each system data similar to those
which are presented for the first system dealt with in each division of the report,
namely, the Niagara system. In order, therefore, to possess a ready grasp of all
the figures presented in this and other similar reports of the Commission, all
that is necessary is to have a true understanding of the financial procedure
followed in connection with one system and with one municipal "Hydro" utility.
The accounts of the Hydro-Electric Power Commission of Ontario are
verified by auditors specially appointed by the Provincial Government. The
accounts of the "Hydro" utility of each individual municipality are prepared
according to approved and standard practice and are also duly audited.
Tabular Data
The first tabular statement given in Section IX is a general balance sheet
exhibiting the assets and liabilities of the undertaking and relates to the properties
constructed or otherwise acquired and being operated by the Commission as
trustee for the municipalities of the various systems.
The general balance sheet is followed by groups of statements relating in
turn to each system of the Commission. These statements, for each system,
are similar in character and include: —
Operating Account for the year, showing, for the system as a whole,
the various items of operating expense and fixed charges entering into the
cost of power as defined by the Power Commission Act, and the revenues
collected by the Commission from the partner municipalities and other
consumers.
Cost of Power statement, which shows the apportionment to each
municipality or rural power district of the items of cost summarized in the
Operating Account, as well as the apportionment of the capital expenditures
listed in the balance sheet and the amount of power taken by each muni-
cipality. It should be appreciated that the cost of power given in this table
is the wholesale cost, — that is, the cost which the Commission receives for
the power delivered from the main transformer stations serving the local
utility or rural power district. In the case of rural power districts, the costs
of power for the respective districts appear also in the "Rural Operating"
statement, immediately following, as "Cost of power delivered"; in the case
of municipal electrical utilities not directly administered by the Commission,
the respective costs of power appear in Statement "B" of Section X as
"Power purchased."*
Rural Operating statement, which shows for each rural power district
the various items of cost, and the revenues received, in connection with the
distribution of electrical energy to consumers.
Credit or Charge statement, which shows the adjustments made in
order to bring the amounts paid by each municipal electric utility to the
actual cost of service to that municipality. These credits and charges are
taken up and given effect to in the municipal accounts of "Hydro" utilities
before the operating records of each year are c losed .
*Consult footnote on previous page.
B6 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
Reserve for Renewals, which shows the provisions made for, the
expenditures from, and the balances to the credit of, this fund.
Reserve for Obsolescence and Contingencies, which gives similar
information with respect to this reserve.
Sinking Fund statement, which gives the accumulated total of the
amounts paid by each municipality and rural power district as part of the
cost of power together with its proportionate share of other sinking funds.
Sinking Fund Reserve, which summarizes the provisions made with
respect to this fund.
All municipal "Hydro" utilities have current expenses to meet similar to
the expenses of the Commission and have adopted the same financial procedure
with respect to their operations. In other words, concurrently with the creation
of funds to liquidate their debt to the Commission and to provide the necessary
reserve to protect generating, transforming, and transmission systems, the
municipalities are taking similar action with respect to their local "Hydro"
utility systems.
The balance sheets, operating reports and statistical data appearing in
Section X, under the heading of "Municipal Accounts," relate to the operation
of local distribution systems by individual municipalities which have contracted
with the Commission for their supply of electrical energy. To this section there
is an explanatory introduction to which the reader is specially referred.
To illustrate further the foregoing explanatory comments, there is presented
herewith a typical operating statement of an Ontario municipal electrical utility,
covering its financial operations, both as a partner in a system of the Hydro-
Electric Power Commission, and as administrator of its own local distribution
system.
FERTH "HYDRO" UTILITY
A Typical Operating Statement for the year 1933
Revenue
Collected from Perth "Hydro" customers for year $61,537. 70
Expenses
A. — Incurred by the Hydro-Electric Power Commission on behalf
of the municipality of Perth in connection with the supplying of
its electrical energy. These data show — as determined by annual
adjustment — what it costs the Commission to supply the municipality
with its wholesale power. See "Cost of Power" statement, page 238,
for the Town of Perth as follows:
Cost (proportionate share) of power purchased for
Eastern Ontario system, from generating plants not
owned by Commission $8,855 . 40
Cost (proportionate share) of operation and maintenance
expense of Eastern Ontario generating plants, trans-
former stations and transmission lines together with
administrative expenses 7,227 . 15
Interest, including exchange, on Perth's proportionate
share of capital investment in generating plants,
transformer stations and transmission lines 10,822.48
1934 HYDRO-ELECTRIC POWER COMMISSION \37
Renewal reserve (proportionate share) provided in
respect of generating plants, transformer stations
and transmission lines $2,968 . 15
Obsolescence and contingencies reserve (proportionate
share) provided in respect of generating plants,
transformer stations and transmission lines 873.66
Sinking Fund (proportionate share) provided in respect
of generating plants, transformer stations and
transmission lines 2,269 . 89
Cost in excess of revenue from power sold to private
companies* 5,005 . 70
$38,022.43
B. — Incurred by the municipality of Perth through its utility
commission in connection with the sale of electrical energy to con-
sumers. Consult the section dealing with the Municipal Accounts:
Operation, maintenance and administrative expenses. . . . $8,648.87
Interest on debenture debt, etc 2,880.45
Sinking fund and principal payments on debentures 1,819.09
Depreciation and other reserves 3,224. 00
$16,572.41
Total Expenses
Charged against revenue from customers of the Perth System. . $54,594.84
Net Surplus for the year $6,942 . 86
The municipality of Perth, situated in the south eastern part of the
Province, was connected to the Eastern Ontario system in February, 1919.
With the close of the fourteenth year of operation, this utility's total assets are
$220,342.86, liabilities $57,695.17, and reserves and surplus, $162,647.69, as
shown in the municipalities' balance sheets, in Section X, Statement "A."
By reference to this municipality's balance sheet, it will be noted that the
Perth "Hydro" utility has created a sinking fund equity amounting to
$34,151.00 in the Hydro-Electric Power Commission system.
By reference to Statement "D" in Section X of this report it will be seen
that under the low rate schedules prevailing throughout the Province, the rates
in force in Perth have resulted in average costs] to the various classes of service
as follows: Domestic service (with an average monthly consumption per
consumer of 93 kilowatt-hours) 2.2 cents per kilowatt-hour; commercial light
service 2.8 cents per kilowatt-hour. The actual rates in force are presented in
Statement "E" and particulars of street lighting service are given in Statement
"C"
This represents the difference between the revenue received from private companies and
other power customers operating under flat-rate contracts, and the result obtained by "costing"
these loads on exactly the same basis as that used in determining "costs" in respect of municipal
contracts, including sinking fund and other reserves.
flf proper differentiation be made by those undertaking research, between the very different
entities of rates on the one hand and the derived quantities of average costs or revenues on the
other, a great deal of confusion and misrepresentation will be avoided. Consult introduction
to Statement "D" of Section X.
138 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
HYDRO-ELECTRIC POWER
Detailed Statement of Assets
POWER UNDER
Assets
Niagara System:
Generating Plants:
Queenston-Chippavva development $76,891,330. 14
Ontario Power development, including water rights. . . . 22,035,794.89
Toronto Power development, including water rights. . . . 11,522,054.50
Chats Falls power development 6,167,756.08
DeCew power development and steam plant, including
water rights 11,824,138.13
Transmission Lines:
Right-of-way . 8,428,947 . 36
Steel-tower and wood-pole lines 25,784,995 . 12
Transformer Stations 35,257,130.56
$197,912,146.78
Distribution Lines:
Rural power districts $6,440,310.91
Rural lines 35,527 . 44
Local distribution systems 422,618.53
6,898,456.88
$204,810,603.66
Share capital of Hamilton Street Railway Company carried
at a value of $3,000,000 . 00
Cash advances to Hamilton Street Railway to cover capital
expenditures and for working capital 250,837 . 27
3,250,837.27
Radial Railways in vicinity of Hamilton in process of liquidation — balance
expected to be recovered 81,986 .56
Balances owing under agreements covering
sales of certain properties, plants and
equipment:
By City of Hamilton $1,812,500.00
By City of Brantford 116,000.00
By Canada Coach Lines, Limited. ... $525,000.00
Accrued interest thereon 8,845 .82
533,845.82
Shares (1,000) of First Preferred stock of Canada Coach
Lines, Limited— at par 100,000.00
2,562,345.82
Thunder Bay System:
Nipigon generating plants $15,688,226.21
Transmission lines 1,913,736.96
Transformer stations 974,870.00
$18,576,833.17
Distribution lines:
Rural power districts 53,939 .01
18,630,772.18
Carried forward $229,336,545.49
1934 HYDRO-ELECTRIC POWER COMMISSION 139
COMMISSION OF ONTARIO
and Liabilities, October 31, 1933
TAKINGS
Liabilities
To Province of Ontario:
Cash advances for Niagara and other systems $204,973,166. 14
Less: Repayment under provisions of Power Commission Act 17,008,616.73
$187,964,549. 41
Grant funds in the hands of the Commission to apply against
rural power districts in course of construction or
extension 40, 1 14 . 69
Amount received from the Province for the purpose of making
loans under provisions of the Rural Power District Loans
Act $85,000.00
Note: Loans made to October 31, 1933, $84,912.64.
Less: Principal instalments on such loans collected and
repaid to the Province 19,395 . 86
65,604.14
Debentures issued by the Commission and guaran-
teed by the Province of Ontario:
Four per cent debentures, due 1957, issued in
purchase of Ontario Power Company of
Niagara Falls $8,000,000.00
Interest accrued thereon 80,000.00
$8,080,000.00
Six per cent debentures, due 1941, issued for
the purpose of retiring the 1921 issue of the
Ontario Power Company of Niagara Falls. $3, 200,000. 00
Interest accrued thereon 67,856.16
3,267,856.16
Six per cent debentures, due 1940, issued in
purchase of the Toronto Power Company
Limited $413,200.00
Interest accrued thereon 10,330.00
423,530.00
Six per cent, debentures, due 1940, issued in
purchase of certain electrical power equip-
ment of the Toronto and York Radial
Railway $205,800.00
Interest accrued thereon 5,145 .00
210,945.00
Five per cent debentures, due 1939, issued for
the purpose of retiring the 1924 issue of
the Toronto Power Company Limited $4,000,000.00
Interest accrued thereon 75,000 .00
4,075,000.00
Four per cent debentures, due 1958, issued in
purchase of distribution lines of Essex
County $200,000 00
Interest accrued thereon 3,333 .34
203,333 . 34
$16,260,664 . 50
Carried forward $188,070,268. 24
HO TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
HYDRO-ELECTRIC POWER
Detailed Statement of Assets
POWER UNDER
Assets
Brought forward $229,336,545.49
Georgian Bay System:
Generating plants $3,771,083 .28
Transmission lines 2,602,025 .41
Transformer stations 1,159,113 .39
$7,532,222.08
Distribution lines:
Rural power districts $780,691 . 26
Rural lines 2,807.43
Local distribution systems 78,924.48
862,423.17
8,394,645.25
Eastern Ontario System:
Generating plants, including water rights $10,114,637.74
Surveys and engineering re power sites:
On St. Lawrence river $734,873 .31
On Ottawa river 94,135.20
829,008.51
Properties purchased for power sites 52,533 .33
Transmission lines 3,926,845 . 19
Transformer stations 2,552,680.41
Rural power districts $1,619,158.39
Local distribution systems:
Electric 108,573 .01
Gas 26,534.67
Rural lines 90,302 . 26
Pulp Mill 52,559 .93
1,897,128.26
19,372,833.44
Northern Ontario Properties — comprising the Nipissing,
Wahnapitae, Abitibi-Sudbury and Patricia (Ear Falls)
Districts as follows:
Nipissing District:
Generating plant $1,102,909.40
Transmission lines 172,660.81
Transformer stations 15,814 .00
$1,291,384.21
Rural power districts $19,254 . 45
Local distribution systems 361,065 .83
380,320.28
Wahnapitae District:
Properties, buildings, plant, equipment and water rights
on Wahnapitae river $2,516,994.40
Transmission lines 139,015 . 15
Transformer stations 43,804 .00
$2,699,813.55
Local distribution systems 6,630 . 43
1.671,704.49
2,706,443.98
Carried forward $261,482,172.65
1934 HYDRO-ELECTRIC POWER COMMISSION 14]
COMMISSION OF ONTARIO
and Liabilities, October 31, 1933
TAKINGS — Continued
Liabilities
Brought forward $16,260,664.50 $188,070,268.24
Debentures issued by the Commission and guaranteed by the
Province of Ontario — Continued.
Four per cent debentures, due 1958, issued in
purchase of distribution lines in vicinity of
Thorold $100,000.00
Interest accrued thereon 1,666.67
101,666.67
Four and three-quarter per cent debentures,
due 1970, issued in part purchase of Under-
takings and Companies from Dominion
Power and Transmission Company, Limited
as at January 1, 1930 $13,000,000.00
Interest accrued thereon 206,397 . 00
13,206,397.00
Five per cent Debentures, due 1935, issued
in part purchase of Undertakings and
Companies from Dominion Power and
Transmission Company, Limited, as at
January 1, 1930 $8,000,000.00
Interest accrued thereon 133,698 . 00
8,133,698.00
37,702,426.17
Four and one-half per cent debentures, due
1938, issued to retire Guaranteed Deben-
ture Stock and other debentures $6,000,000.00
Interest accrued thereon 67,500.00
$6,067,500.00
Twenty-year debentures maturing in 1952 and
bearing interest at the rates of 33^% in
first five years, 4% in next five years, 5%
in last ten years, issued in purchase of
bonds of Ontario Power Service Corpora-
tion Limited, which bonds were in turn sur-
rendered in the purchase of the properties
and assets of that Company $17,626,950.00
Interest accrued thereon 50,707 . 66
17,677,657.66
23,745,157.66
Bonds and debenture stock assumed by the Commission and
guaranteed by the Province of Ontario:
First mortgage 5 % gold bonds, due 1943, of the
Ontario Power Company of Niagara Falls:
Amount assumed at date of purchase of Com-
pany by Commission, August 1, 1917. . . .$9,834,000.00
Less: Retired by the Commission 2,042,000.00
$7,792,000.00
Interest accrued thereon 97,400 .00
$7,889,400.00
First mortgage 5 % gold bonds, due 1945, of the
Ontario Transmission Company, Limited:
Amount assumed at date of purchase of Com-
pany by Commission, August 1, 1917. . . .$1,772,000.00
Less: Retired by the Commission 497,000.00
$1,275,000.00
Interest thereon payable November 1, 1933 31,875 .00
1,306,875.00
$9,196,275.00
Carried forward $249,517,852.07
42
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
Brought forward
Assets
HYDROELECTRIC POWER
Detailed Statement of Assets
POWER UNDER
$261,482,172.65
Northern Ontario Properties — Continued.
Abitibi-Sudbury District:
Abitibi Canyon generating plant (uncompleted) and
adjacent lines $16,729,782 .45
Hunta-Copper Cliff line 2,197,690.87
Meter station at Copper Cliff 2,290 . 63
Note. — The assets of Ontario Power Service Corporation
Limited acquired by the Commission — on behalf of the
Province — consisted of:
(1) The uncompleted Abitibi Canyon Development and
Lines upon which $15,146,607.31 has been expended;
(2) $2,697,392.69 unexpended cash in the hands of the
Trustee and Receiver, and the purchase price of
$14,000,000 was paid:
(a) In twenty-year debentures of the Commission,
guaranteed by the Province, maturing in 1952 and
bearing interest at the rates 33^ per cent in first five
years, 4 per cent in next five years, 5 per cent in last
ten years — to the amount of $17,626,950, and
(b) In cash $290,150 to the Receiver:
From the par value of the above mentioned
bonds $17,626,950.00
may be deducted the amount of cash
turned over to the Commission by
the Receiver 2,697,392 .69
and to the balance is added:
(1) The cash paid to the Receiver, as
above
In settlement of certain claims
Expenditures by the Commission to
31st October, 1933 incidental to the
purchase of the properties and to-
wards completion of such properties
$14,929,557.31
(2)
(3)
290,150.00
57,406.22
1,452,668.92
Total to 31st October, 1933 — as shown
above $16,729,782.45
and leaving in the hands of the Com-
mission a balance in cash of
$897,167.55
Patricia District:
Ear Falls generating plant.
Manitoulin Island:
Transformer station ,
Rural power district
Bonnechere River Storage:
Round Lake dam
Service Buildings and Equipment:
Service buildings and equipment, Toronto
Terminal building, Hamilton
Equipment of storehouse and garage, Hamilton
Pole yard and equipment, Cobourg
18,929,763.95
$5,098.11
27,527.68
482,224.95
32,625.79
51,629.23
$508,098.10
750,000.00
3,666.40
21,629.08
1,283,393.58
Carried forward $282,261,810. 15
1934 HYDRO-ELECTRIC POWER COMMISSION [43
COMMISSION OF ONTARIO
and Liabilities, October 31, 1933
TAKINGS— Continued
Liabilities
Brought forward $9,196,275.00 $249,517,852.07
Guaranteed 43^% debenture stock, due 1941, of the Toronto
Power Company, Limited:
Amount assumed at date of purchase of Com-
pany by Commission, December 1, 1920. $13,558,917.81
Less: Retired by the Commission 13,483,056.18
$75,861.63
Premium of 5 % payable under terms of Trust
deed because of notice to retire before
maturity 3,793.08
79,654.71
First mortgage 5 % gold bonds, due 1933, of the
Electrical Development Company of Ontario,
Limited:
Amount assumed at date of purchase of Com-
pany by Commission, December 1, 1920. . $4,335,000.00
Less: Retired by the Commission 4,328,500.00
6,500.00
9,282,429.71
Other debentures assumed:
In respect of purchase of lines at Streetsville:
Amount assumed at date of purchase. . . $6,000.00
Less: Retired by the Commission 5,541 .46
$458.54
Interest accrued thereon 11 .46
$470.00
In respect of purchase of original Muskoka
Power Development:
Amount assumed at date of purchase. . . $50,595 .93
Less: Retired by the Commission 34,101 . 75
$16,494.18
Interest accrued thereon 634 . 34
17,128.52
In respect of purchase of sundry rural lines:
Amount assumed at dates of purchase. . $69,289.85
Less: Retired by the Commission. ...... 35,571 .24
$33,718.61
Interest accrued thereon 872 .47
34,591.08
Outstanding share capital of the Electrical Development
Company of Ontario, Limited $600.00
Galetta Electric Power and Milling Company Limited 580.00
52,189.60
1,180.00
659,503.42
Carried forward ■ $259,513,154.80
Accounts payable $602,435 .60
Interest coupons due but not yet presented for payment. . . . 57,067 .82
H4 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
HYDRO- ELECTRIC POWER
Detailed Statement of Assets
POWER UNDER
A CCCTC
Brought forward $282,261,810. 15
Office Buildings:
On University avenue, Toronto $525,007.00
On proposed new building 138,450 . 36
On corner Elm street and Centre avenue, Toronto 160,821 .95
824,279.31
Office Furniture and Equipment:
At Toronto office $61,829.27
At Electrical Inspection office 6,876 . 22
68,705.49
Automobiles and Trucks 3,737 . 67
Inventories:
Construction and maintenance tools and equipment $831,094.20
Construction material and sundry supplies 894,564.34
Maintenance material and supplies 631,837 .30
Stationery and office supplies 24,990 . 91
2,382,486.75
Sinking Funds:
Employed to make repayments to the Province
of Ontario under the terms of the Power
Commission Act $17,008,616.73
Employed in retirement of bonds issued or
assumed by the Commission and guar-
anteed by the Province of Ontario 7,991,128.38
Invested in securities of the Province of Ontario, which stand:
(a) Deposited with the Provincial Treasurer— par value,
$2,101,000.00 . $2,087,573 .08
(b) In the hands of the Commission — par value,
$300,000.00 295,200.00
Interest accrued thereon 33,162.01
2,415,935.09
Insurance Funds:
(a) Invested in securities of the Dominion of Canada — par
value, $800,000.00. $802,430.84
(b) Invested in securities of the Province of Ontario — par
value, $28,000.00 28,727 . 24
Interest accrued thereon 616.53
$831,774.61
(c) On deposit with Workmen's Compensation Board 48,543 .01
880,317.62
Staff Pension Funds:
(a) Invested in securities of the Province of Ontario — par
value, $3,270,000.00 $3,235,755.95
(b) Invested in securities of the Dominion of Canada — par
value, $95,000.00 93,427.00
Interest accrued thereon 37,250 . 14
3,366,433.09
Carried forward $292,203,705. 17
1 934 HYDRO-ELECTRIC POWER COMMISSION 143
COMMISSION OF ONTARIO
and Liabilities, October 31, 1933
TA KINGS— Continued
Liabilities
Brought forward $259,513,154.80
Bank of Montreal:
Short term loan (guaranteed by Province of Ontario) 2,500,000 .00
Other short term loan (secured by pledge of Dominion of
Canada and Province of Ontario Bonds) 3,300,000.00
Insurance Department:
Outstanding claims and awards $816,542 . 62
Surplus 121,561 .38
938,104.00
Reserve for Staff Pensions 3,384,757 .69
Balances due to Municipalities following the annual adjustments
in respect of power supplied to them up to October 31, 1933,
in reduction of the amounts charged to them by monthly
interim bills:
Niagara system $810,579.69
Georgian Bay system 74,760 . 04
Eastern Ontario system 131,601 .92
Nipissing rural power district 8,987 .75
1,025,929.40
Reserves for Sinking Fund:
Niagara system $24,564,512 . 19
Niagara rural lines 14,046 . 12
Thunder Bay system 1,063,953 .45
Georgian Bay system 936,659 . 56
Georgian Bay rural lines 846 .41
Eastern Ontario system 1,064,379.57
Nipissing rural power district 682 . 76
Bonnechere storage 3,536 .97
Manitoulin rural power district 285 .45
$27,648,902.48
Service buildings and equipment 120,334 . 12
Office buildings 156,249 . 61
27,925,486.21
Reserves for Renewals:
Niagara system $18,686,189.89
Niagara rural lines 6,204 . 62
Thunder Bay system 1,325,319.49
Georgian Bay system 1,454,220.59
Georgian Bay rural lines 517.15
Eastern Ontario system 3,142,627 .03
Northern Ontario properties 413,679 . 10
Nipissing rural power district 3,800 .33
Manitoulin rural power district 996.29
$25,033,554.49
Service buildings and equipment 315,079 .89
Office buildings 115,185 .37
25,463,819.75
Carried forward $324,051,251.85
146 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
HYDROELECTRIC POWER
Detailed Statements of Assets
POWER UNDER
Assets
Brought forward $292,203,705.17
Reserve Funds:
(a) Invested in securities of the Dominion of Canada — par
value, $2,501,850.00 $2,503,517.83
(b) Invested in securities of the Canadian National Railway,
guaranteed by the Dominion of Canada — par value,
$50,000.00 52,592 .03
(c) Invested in securities of the Province of Ontario — par
value, $29,618,500.00 29,207,884.53
(d) Invested in securities of the Commission guaranteed by
the Province of Ontario— par value, $1,200,000.00. . . 1,185,212.40
(e) Invested in securities of the Temiskaming and Northern
Ontario Railway, guaranteed by the Province of
Ontario— par value, $240,000.00 207,01 1.57
(f) Invested in debentures of Ontario municipalities, which
debentures were received from certain municipalities
upon the sale thereto of their local distribution
systems— par value, $1,439,244.34 1,324,159 .94
Interest accrued thereon 425,111 .98
Other bonds and shares taken over with the plant assets of power
companies acquired — carried at a value of $24,915.00 $24,915 .00
Interest accrued thereon 332 .51
34,905,490.28
25,247.51
Cash:
In banks $2,066,558.17
In banks to pay debenture stock and bonds overdue but not
presented 86,154.71
In banks to pay bond interest due November 1, 1933, and
interest coupons overdue but not presented 88,942 .82
Sinking funds on deposit with trustees for bondholders 775 .57
In hands of employees as'advances on account of expenses . . . 76,532 .71
$2,318,963.98
Less: Funds of Guelph Radial Railway shown elsewhere in
this balance sheet 6,846 . 28
2,312,117.70
Accounts Receivable:
Due by municipalities and sundry customers
in respect of construction work, supply
sales, etc $323,007.42
Less: Reserve for doubtful accounts 22,797 . 14
Due by municipalities and sundry customers
in respect of power accounts $4,091,739.92
Less: Reserve for doubtful accounts 665,798.60
$300,210.28
3,425,941.32
Sinking fund and interest accounts owing in respect of rural
lines 3,848.04
3,729,999.64
Carried forward $333,176,560.30
1934 HYDRO-ELECTRIC POWER COMMISSION 147
COMMISSION OF ONTARIO
and Liabilities, October 31, 1933
TA KINGS— Continued
Liabilities
Brought forward $324,051,251.85
Reserves for Obsolescence and Contingencies:
Niagara system $9, 106,600 . 64
Niagara rural lines 3,047 .63
Thunder Bay system 715,396.31
Georgian Bay system . . . . : 429,836.32
Georgian Bay rural lines 222.36
Eastern Ontario system 1,131,109.22
Northern Ontario properties 211,603.46
Nipissing rural power district 1,317 .98
Manitoulin rural power district 476 .90
11,599,610.82
Balance at credit of Interest Account 20,221 . 23
Contingent Liabilities:
In respect of contracts entered into for power undertakings
in course of construction, $165,265.78.
Carried forward $335,671,083.90
H8 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
HYDRO-ELECTRIC POWER
Detailed Statement of Assets
POWER UNDER
Assets
Brought forward $333,176,560.30
Balances due by Municipalities — following the annual adjust-
ment — in respect of power supplied to them up to October
31, 1933, in addition to the amounts charged to them by
monthly interim bills:
Niagara system $484,288 . 1 1
Georgian Bay system 111,697.27
Eastern Ontario system 88,975 .05
Thunder Bay system 101,293.11
Manitoulin rural power district 1,383 .84
787,637.38
Rural Loans:
Loans made to persons under provisions of the Rural Power
District Loans Act in respect of installations of electrical
equipment $84,912 .64
Instalments of principal received 20,767 . 22
$64,145.42
Interest instalments due 896.83
Work in Progress:
Expenditures to date incidental to Water
Heater Campaign, including purchases of
materials, also engineering, administration,
printing, advertising, etc $387,693 .89
Less: portion written off against revenue in
year ending October 31, 1933 63,547 . 14
Expenditure on account of various systems
chargeable upon completion to:
Capital construction $22,011 .36
Operating and maintenance expenses 22,553 .65
$324,146.75
44,565.01
65,042.25
368,711.76
Insurance Unexpired 37,242 .26
Discount on Debentures issued by the Commission, less amounts
written off:
On debenture issue of $3,200,000 maturing 1941 $67,650 .81
On debenture issue of $4,000,000 maturing 1939 41,018.40
108,669.21
Total Power Undertakings $334,543,863. 16
1934 HYDRO-ELECTRIC POWER COMMISSION 149
COMMISSION OF ONTARIO
and Liabilities, October 31, 1933
TA KINGS— Continued
Liabilities
Brought forward $335,671,083.90
Total Power Undertakings $335,671,083.90
150 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
HYDROELECTRIC POWER
Detailed Statement of Assets
RADIAL RAILWAY
Assets
Brought forward $334,543,863. 16
Guelph Radial Railway:
Road and equipment $444,205 . 06
Materials and supplies 5,499 . 14
Reserve funds:
(a) Invested in securities of the Province
of Ontario— par value, $25,000.00 $22,534.90
(b) Invested in securities of the Dominion
of Canada— par value, $25,000.00 24,779.92
Interest accrued thereon 1,057.66
48,372.48
Cash:
In the general bank account of the Com-
mission at Toronto $6,846 . 28
In bank at Guelph 1,496.99
In hands of employees as advances on
account of expenses 900 .00
9,243.27
Accounts receivable: $1 , 782 . 1 2
Less: Reserve for doubtful accounts 500.00
1,282.12
Insurance and expenses prepaid 1 ,014 . 90
Due by the City of Guelph:
Operating deficit for the year ending
October 31, 1933 — as per Operating
Account $41,332 .32
Less: Paid on account, by the City 38,000.00
3,332.32
512,949.29
Sandwich, Windsor & Amherstburg Railway Company:
Undertakings of the Sandwich, Windsor and Amherstburg
Railway Company to pay the Hydro Radial Debentures
issued by the Commission, and guaranteed by the
Province of Ontario, in purchase of, and for the extension
and betterment of, the Sandwich, Windsor and Amherst-
burg Railway — as per agreement covering the transfer
at July 31st, 1931, of the Railway, by the Commission,
to the Company $5,816,205 .00
Interest accrued on such debentures 61,839 . 63
Note. — The Hydro Radial Debentures above mentioned
(and which are also listed opposite as liabilities of the
Commission) are — under Statute of 1930 and under
Trust Deed, dated July 31, 1931, in favour of the
Guaranty Trust Company, as Trustee — secured by:
(a) A charge upon the properties of the Railway.
(b) Debentures of the eleven municipalities which
own the Railway Company, to the aggregate
amount of $5,816,205.00. 5,878,044 . 63
Carried forward $340,934,857.08
1934 HYDRO-ELECTRIC POWER COMMISSION \5\
COMMISSION OF ONTARIO
and Liabilities, October 31, 1933
UNDER TA KINGS— Continued
LlABILITES
Brought forward $335,671,083.90
In respect of the Guelph Radial Railway:
City of Guelph — purchase price of the Railway
payable thereto, in half yearly instalments
according to purchase agreement $150,000 .00
Less: Twenty- five instalments thereon. . . 81,856.05
$68,143.95
Debentures issued by the Commission and
guaranteed by the Province of Ontario:
Five per cent Debentures due 1970, issued
for the purpose of making extensions
and betterments 300,000.00
Accounts payable and accrued charges $794.42
Provision for unredeemed tickets 1,300.00
2,094.42
Premium on sale of debentures — less portion written off. . . . 21,229. 14
Reserve— created by payment of instalments on the purchase
price out of the revenue of the road and assessments
against the City of Guelph ' 81,856.05
Reserve for sinking fund 8,152 . 75
Reserve for renewal of road and equipment 31,472 .98
In respect of the Sandwich, Windsor & Amherstburg Railway
Company:
Debentures issued under provisions of the Hydro-Electric
Railway Act, by the Commission and guaranteed by
the Province of Ontario in purchase of the Railway and
for the purpose of making extensions and betterments
thereto.
Four and one-half per cent debentures, due April 1, 1960 $2,100,000.00
Six per cent debentures, due July 1, 1961 900,000 .00
Five per cent debentures, due September 1, 1943 966,205 .00
Five per cent debentures, due July 1, 1945 750,000.00
Five per cent debentures, due September 1, 1945 100,000.00
Five per cent debentures, due July 15, 1946 1,000,000.00
$5,816,205.00
Interest accrued thereon 61,839.63
512,949.29
5,878,044.63
Carried forward $342,062,077.82
152 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
HYDRO-ELECTRIC POWER
Detailed Statement of Assets
RADIAL RAILWAY
Assets
Brought forward $340,934,857.08
Toronto and York Radial Railway:
City of Toronto — debentures held as collateral security for
the repayment of the Hydro Radial debentures issued in
purchase of the Toronto and York Radial Railway — as
per agreement covering the transfer (in January, 1927)
of the railway to the City of Toronto $2,375,000.00
City of Toronto — interest accrued on $2,375,000 debentures
issued by the Commission in purchase of the Toronto
and York Radial Railway 59,375 .00
2,434,375.00
Port'Credit to St. Catharines Radial Railway:
Purchase of right-of-way and carrying charges (taxes, less
rental revenue) down to October 31, 1933 $73,421 .81
Construction materials purchased, less amount realized on
sale thereof 117,510.09
Surveying, engineering, administrative expenses and interest 399,969.62
590,901.52
Toronto to Port Credit Radial Railway:
Purchase of right-of-way and carrying charges (taxes, less
rental revenue) down to October 31, 1933 — less amounts
realized on properties sold $486,044 . 65
Surveying, engineering, administrative expenses and interest 550,274.57
1.036,319.22
Total $344,996,452.82
1934 HYDRO-ELECTRIC POWER COMMISSION 153
COMMISSION OF ONTARIO
and Liabilities, October 31, 1933
UNDERTAKINGS— Continued
Liabilities
Brought forward $342,062,077.82
In respect of Toronto and York Radial Railway:
Debentures issued by the Commission and guaranteed by
the Province of Ontario:
Six per cent debentures, due 1940, issued in purchase
of the Metropolitan, Scarboro and Mimico
Radial Railway divisions $2,375,000.00
Interest accrued thereon 59,375 .00
2,434,375.00
In respect of the Port Credit to St. Catharines Radial Railway:
Bank of Montreal — advances (secured by hypothecation of $1,200,000 Hydro
Radial debentures, being part of an issue of $11,360,363 guaranteed by
the Province of Ontario) 500,000 . 00
Totai $344,996,452.82
154 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
NIAGARA
Operating Account for the
Costs of operation as provided under the terms of the
Power Commission Act
Power purchased $6,738,406 . 63
Costs of operation and maintenance, including the proportion of
administrative expenses chargeable to the operation of
this system:
Generation and transmission equipment $4,187,507.27
Rural power districts 557,105 .44
Water heater costs written off in year to extent of revenue
available from water heater loads 55,561 .07
4,800,173.78
Interest (including exchange thereon) on capital investment in:
Generation and transmission equipment $10,151,547.62
Rural power districts 294,442 .54
10,445,990.16
Provision for renewals of:
Generation and transmission equipment $1,376,778.87
Rural power districts 251,397.57
1,628,176.44
Provision for obsolescence and contingencies in respect of:
Rural power districts $125,698 . 79
125,698.79
Provision for sinking funds for repayment of the cash advances by
the province of Ontario to the Commission and for the
retirement of the bonds issued by and assumed by the
Commission:
By charges included in the cost of power delivered to munici-
palities and rural power districts $1,385,325 .62
By charges against contracts with private companies which
purchased pow r er and local distribution systems 431,003 .02
By charges included in the cost of distribution of power within
rural power districts 66,871 .35
1,883,199.99
Total costs of operation $25,621,645.79
Deduct:
Cost to the Commission (including provisions for sinking fund
$431,003.02 and renewals $312,153.93) of power delivered
to private companies and customers under flat rate
contracts, in excess of the revenue received from them —
which excess has been charged against the Contingency
Reserve of the system $2,221,034.43
Amount appropriated from the Contingency Reserve of the
system and applied proportionately to each municipality
in. reduction of the costs of operation 2,015,572 .30
4,236,606.73
$21,385,039.06
1934 HYDRO-ELECTRIC POWER COMMISSION 155
SYSTEM
Year Ending October 31, 1933
Revenue for Period
Amounts received from (or billed against) each municipality by
the Commission $15,136,167.92
Power sold to private companies and customers, also miscellaneous
revenue 3,817,900 .47
Amounts received from (or billed against) customers in rural power
districts . 2,063,370 . 73
Power supplied at cost to Sandwich, Windsor & Amherstburg
Railway Company and certain fixed < harges billed against
Windsor, Essex & Lake Shore Electric Railway Association.. 79,282.94
$21,096,722.06
Add:
Amounts due by certain municipalities, being the difference
between the sums received (or billed) at interim rates
and the amounts charged — following annual adjustment —
in respect of power supplied in the year $320,603 .06
Amounts due by municipalities comprising certain rural power
districts, being the difference between the sums received
from (or billed against) customers therein and the amounts
charged to such districts — following annual adjustment —
in respect of power supplied in the year 92,501 .40
413,104.46
$21,509,826.52
Deduct:
Amounts received from (or billed against) certain municipali-
ties at interim rates in excess of the amounts charged —
following annual adjustment — in respect of power supplied
in the year $74,541 .31
Amounts received from (or billed against) customers in certain
rural power districts in excess of the amounts charged to
such districts — following annual adjustment — in respect
of power supplied in the year 50,246 . 15
124,787.46
Revenue $21,385,039.06
$21,385,039.06
Note — Operating account of Hamilton Street Railway Company is shown on page 274.
156
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
NIAGARA
Statement showing the amount chargeable (upon annual adjustment) to each
by the Commission; the amount appropriated from the contingency
cost; the amount received by the Commission from each
charged to each Municipality in respect of power
Municipality
Interim rates
per
horsepower
collected by
Commission
during year
To
Jan. 1
1933
To
Oct. 31
1933
Share of
capital cost
of system on
which
interest and
fixed charges
are payable
Average
horse-
power
supplied
in year
after
correction
for power
factor
Cost of
power
pur-
chased
Share of operating
Operating,
main-
tenance
and
adminis-
trative
expenses
Interest
(including
exchange)
Acton
Water heater load.
Agincourt
Water heater load.
Ailsa Craig
Alvinston
Amherstburg
Water heater load.
Ancaster twp
W 7 ater heater load
Arkona
Aylmer
Water heater load
Ayr
Baden
Beachville
Water heater load
Belle River
Water heater load
Blenheim
Water heater load
Blyth
Bolton
Water heater load
Bothwell
Water heater load
Brampton
Water heater load
Brantford
Water heater load
Brantford twp
Water heater load
Bridgeport
Water heater load
Brigden.
Brussels
Bur ford. . . .
Burgessville
Caledonia. .
$ c.
33.00
40.00
48.00
90.00
40.00
30.00
75.00
35.00
35.00
32.00
33.00
38.00
39.00
58.00
46.00
45.00
29.00
$ c.
33.00
40.00
48.00
90.00
38.00
30.00
75.00
35.00
34.00
32.00
33.00
38.00
39.00
58.00
44.00
45.00
$ c.
243,602.11
4,9,545.82
36,770.85
61,292.09
193,881.50
68,899.46
33,234.98
138,589.66
47,654.46
75,357.51
128.358.54
36,481.80
113,363.81
40,808.82
44,228.76
36,460.59
27.00
29.00
36.00
68.00
54.00
35.00
44.00
29.00
30.00
27.00
30.00
36.00
65.00
54.00
35.00
50.00
29.00
534,738.02
2,800,848.27
144,015.51
'32,429 '42
37,902.77
49,993.30
41,994.31
16,577.41
73,657.68
784.6
2.5
136.3
0.1
89.2
74.9
587.0
9.6
246.2
1.5
52.7
440.6
0.3
162.7
253.7
440.5
0.8
109.1
0.3
336.1
1.8
87.6
119.4
0.8
96.9
0.4
2,003.6
4.8
11,548.4
19.6
551.1
1.2
102.1
0.3
69.6
114.1
140.6
40.1
259.2
$ c.
6,798.72
1,181.07
772.94
649.02
5,086.48
2,133.37
456.66
3,817.89
1,409.83
2,198.36
3,817.02
945
37
2,912
37
759
1,034
07
63
839
66
17,361
60
100,069
22
4,775
39
884
72
603 . 10
988.70
1,218.33
347.48
2,246.02
$ c.
6,021.07
*84 . 89
1,288.89
*3.94
1,636.43
1,937.56
5,161.93
*349.60
1,997.99
*48.43
1,483.80
4,156.84
*10.79
1,592.46
2,146.68
3,529.00
*26.29
1,367.92
*12.14
3,763.76
*70.62
1,544.97
1,291.32
*32.89
1,659.09
*19.01
16,929.76
*151 .59
66,539.77
*555.01
4,999.47
*38.32
1,048.85
•11.16
1,348.57
1,892.64
1,289.39
871.19
2,085.73
$ c
12,201.19
2,460.08
1,769.18
2,888.73
9,666.41
3,497.22
1,596.20
6,913.83
2,392.25
3,734.06
6,433.39
1,816
94
5,603
33
1,984
2,154
35
97
1,752
05
27,085
25
142,183
.68
7,376.35
1,635
.51
1,812.55
2,434.21
2,101.43
806.01
3,700.36
'Heater costs written off in year to extent of revenue available from heater loads.
1934
HYDRO-ELECTRIC POWER COMMISSION
157
SYSTEM
N.—COST OF POWER
Municipality as the Cost — under Power Commission Act — of Power supplied to it
reserve of the system and proportionately applied in reduction of such
Municipality; and the amount remaining to be credited or
supplied to it in the year ending October 31, 1933
costs and fixed charges
Renewals
Sinking
fund
Total
cost of
power
for year
Amount
appropriat-
ed from
contingency
reserve
and pro-
portionate-
ly applied
in reduc-
tion of such
cost
Amounts
charged
to each
municipality
in respect
of power
supplied
to it in
the year
Amounts
received
from
(or billed
against)
each
municipality
by the
Commission
Amounts remaining
to be credited
or charged to each
municipality
Credited
Charged
$ c.
2,085.88
$ c.
2,280.31
442.11
472.07
371.91
765.04
1,685.51
354.57
618.41
1,830.67
545.01
636.47
388.91
1,193.74
330.25
1,299.83
389.78
621.74
1,043.31
443 . 10
701.97
1,192.71
319.92
344.92
1,011.75
1,072.13
433.55
422.60
397.33
422.97
346.85
347.82
4,006.01
4,907.08
21,022 23
25,681.31
1,059.27
1,317.71
281 74
304.64
425.13
517.29
349.21
168.39
587.67
374.03
484.25
391.61
160.12
679.83
$
c.
29,387
.17
84.89
5,844
22
3
94
4,905
.03
6,858
76
23,431
.00
349
60
8,810
06
48
43
4,255
82
17,382
13
10
79
6,227
42
9,402
81
16,015
43
26
29
4,795
07
12
14
14,363
34
70
62
5,119
27
5,326
49
32
89
4,945
47
19
01
70,289
70
151
59
355,496
21
555
01
19,528
19
38
32
4,155
46
11
16
4,563
38
6,317
09
5,349
97
2,353
19
9,299
61
$ c
\ 2,746.10
477
05
312
262
2,054
20
15
50
861
70
184
1,542
45
10
569.45
887.95
1,541.75
381
85
1,176
35
306
417
00
90
339
15
7,012
60
40,419
40
1,928
85
357
35
243 . 60
399.35
492 . 10
140.35
907.20
$
c.
26,641
.07
84
.89
5,367
.17
3
.94
4,592
.83
6,596
.61
21,376
.50
349
.60
7,948
.36
48
43
4,071
37
15,840
03
10
79
5,657
97
8,514
86
14,473
68
26
29
4,413
22
12
14
13,186
99
70
62
4,812
67
4,908
59
32
89
4,606
32
19
01
63,277
10
151
59
315,076
81
555
01
17,599.34
38
32
3,798
11
11
16
4,319
78
5,917
74
4,857
87
2,212
84
8,392
41
$ c.
\ 26,712.95
5,603.20
4,382.79
6,926.75
23,480.33
7,639.28
4,057.01
\ 15,844.65
/
5,702.71
8,346.00
14,952.55
4,262.57
13,517.39
5,205.58
5,471.14
4,487.44
61,536.07
311,164.45
16,904.56
3,782.23
4,674.96
6,313.81
5,047.46
2,004.39
7,732.85
$ c
232.09
330.14
1,754.23
44.74
452.58
259.78
392.91
529.66
355.18
396.07
189.59
$ c.
13.01
210.04
357.51
14.36
6.17
168.86
162.79
137.89
1,892.62
4,467.37
733.10
27.04
208.45
659.56
158
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
NIAGARA
Statement showing the amount chargeable (upon annual adjustment) to each
by the Commission; the amount appropriated from the contingency
cost; the amount received by the Commission from each
charged to each Municipality in respect of power
Municipality
Interim rates
per
horsepower
collected by
Commission
during year
To
Jan. 1
1933
To
Oct. 31
1933
Share of
capital cost
of system on
which
interest and
fixed charges
are payable
Average
horse-
power
supplied
in year
after
correction
for power
factor
Cost of
power
pur-
chased
Share of operating
Operating,
main-
tenance
and
adminis-
trative
expenses
Interest
(including
exchange^
Campbellville
Cayuga
Chatham
Water heater load
Chippawa
Water heater load
Clifford
Clinton. . .
Comber. . .
Cottam. . .
Courtright
Dashwood .
Delaware
Water heater load
Dorchester
Water heater load
Drayton
Water heater load
Dresden
Water heater load.
Drumbo
Water heater load
Dublin
Dundas
Water heater load
Dunnville
Dutton
Water heater load
East Windsor
Water heater load
Elmira
Water heater load.
Elora
Water heater load.
Embro
Water heater load.
Erieau
Water heater load.
Erie Beach
$ c
62.00
50.00
30.00
25.00
59.00
38.00
50.00
44.00
72.00
50.00
38.00
38.00
58.00
45.00
45.00
58.00
25.00
35.00
38.00
31.00
34.00
35.00
50.00
56.00
70'00
$ c
60.00
48.00
30.00
25.00
59.00
38.00
50.00
44.00
72.00
50.00
38.00
38.00
58.00
45.00
45.00
58.00
25.00
34.00
38.00
31.00
34.00
35.00
48.00
56.00
70.00
$ c.
8,554.80
42,983.36
1,069,849.84
43,910.02
"29,254 ! 87
147,343.39
51,719.24
23,215.62
23,042.55
21,950.30
10,460.48
27,127.73
44, 952 .50
99,732.05
21,82^76
18,213.53
323,823.83
225,632.91
63,104.22
680,732.50
187.060.34
92,017.99
34,248.56
31,739.99
6,994.65
25.1
99.2
3,811.3
23.9
196.5
1.9
56.7
436.6
124.7
59.9
39.4
50.2
36.1
1.0
77.4
0.4
89.9
0.1
269.4
0.5
64.0
0.2
36.9
1,285.4
3.5
766.8
210.1
0.1
2,256.0
19.8
580.5
4.1
275.4
0.4
93.4
0.5
69.6
0.1
13.7
$ c
217.50
859.59
33,025.69
1,702.71
491.32
3,783.23
1,080.55
519.05
341.41
434.99
312.81
670
60
779
00
2,334
41
554
57
319
11,138
75
25
6,644
1,820
48
56
19,548
72
5,030
15
2,386
40
809
33
603
10
118.71
$
c.
862
.52
1,892
38
26,834
66
*741
55
1,140
30
*49
.16
1,485
51
4.791
07
1,941
06
725
64
1,361
01
904
58
505
55
*38
75
1,113
01
*16
78
2,165
04
*6
37
3,899
89
*22
43
868
67
*8
39
806
84
6,590
72
*94
27
4,094
26
2.474
00
*3
73
15,469
59
*640.83
5,225
82
*147
12
2,784
70
*15
14
1,472
46
*22
84
1,173
14
*5
36
348
13
S c.
427.57
2,087.01
53,621.29
"2,256.95
1,414 '96
7,275.15
2,502.60
1,151.78
1,105.9?
1,058.20
525.77
1,266
8&
2,167
42
4,898
30
1,080
78-
874.67
16,336.13
11,367
3,160
20
21
34,025
34
9,203
85
4,515
58
1,666.30
1,554.0S
339.44
*Heater costs written off in vear to extent of revenue available from heater loads.
1934
HYDRO-ELECTRIC POWER COMMISSION
159
SYSTEM
N.— COST OF POWER
Municipality as the Cost — under Power Commission Act — of Power supplied to it
reserve of the system and proportionately applied in reduction of such
Municipality; and the amount remaining to be credited or
supplied to it in the year ending October 31, 1933
costs and fixed charges
Rene\
Sinking
fund
Total
cost of
power
for year
Amount
appropriat-
ed from
contingency
reserve
and pro-
portionate-
ly applied
in reduc-
tion of such
cost
Amounts
charged
to each
municipality
in respect
of power
supplied
to it in
the vear
Amounts
received
from
(or billed
against)
each
municipality
by the
Commission
Amounts remaining
to be credited
or charged to each
municipality
Credited Charged
$ c.
78.02
441.34
8,228.93
280.21
323.22
1,320.10
519.74
223.42
264.45
228.54
84.09
226.59
491 '02
944.35
199.47
197.98
2,309.51
1,901.74
525.65
5,511.24
1,642.09
830.70
322^04
333.49
76^85
$ c.
81.01
412.12
9,880.44
391 55
287.09
1,390.10
499.13
222.91
228.43
213.04
96.87
240.19
440.11
953.00
206.70
178.14
2,946.76
2,099.53
589.24
6,357.13
1,760.27
869.57
323~68
309.05
' 68 ". 70
% c.
1,666.62
5,692.44
131,591.01
741.55
5,771.72
49.16
4,002.04
18,559.65
6,543.08
2,842.80
3,301.29
2,839.35
38.75
3,517.36
16.7
6,042 59
6.37
13,029.95
22.43
2,910.19
8.39
2,377.38
39,321.37
94.27
26,107.21
8,569.66
3.73
80,912.02
640 . 83
22,862.18
147.12
11,386.95
15.14
4,593.81
22.84
3,972.86
5.36
951.83
$ c
87.85
347.20
\ 13,339.55
687.75
198.45
1,528.10
436.45
209.65
137.90
175.70
1,525.09 \ 126.35
270.90
\ 314.65
942.90
224.00
129.15
) 4,498.90
2,683 80
\ 735.35
/■
1
/■
7,896.00
\ 2,031.75
/
) 963 90
/
326.90
243 '. 60
47^95
$ c
1,578.77
5,345.24
118,251.46
741.55
5,083.97
49.16
3,803.59
17,031.55
6,106.63
2,633.15
3,163.39
2,663.65
1,398.74
38.75
3,246.46
16.78
5,727.94
6
12,087.05
22.43
2,686.19
8.39
2,248.23
34,822.47
94.27
23,423.41
7,834.31
3.73
73,016.02
640 . 83
20,830.43
147.12
10,423.05
15.14
4,266.91
22.84
3,729.26
5.36
903.88
$ c.
1,543.65
4,912.83
118,469.37
5,091.30
3,431.58
16,535.62
6,385.33
2,703.79
2,910.07
2,574.46
1,441.99
3,028.94
5,355.23
12,447.91
2,953.38
2,138.24
1 33,396.53
26,898.91
1 8,178.43
72,574.41
/
) 20,436.94
9,921.38
4,640.33
3,998.31
981.29
278.70
70.64
4.50
338 A3
258.80
3,475.50
340.39
350.58
263.69
77.41
$ c.
35 . 1 2
432.41
523.64
41.83
372.01
495.93
253.32
89.19
234.30
379.08
109.99
1,520.21
1,082.44
540.61
516.81
160
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
NIAGARA
Statement showing the amount chargeable (upon annual adjustment) to each
by the Commission; the amount appropriated from the contingency
cost; the amount received by the Commission from each
charged to each Municipality in respect of power
Municipality
Interim rates
per
horsepower
collected by
Commission
during year
To
Jan. 1
1933
To
Oct. 31
1933
Share of
capital cost
of system on
which
interest and
fixed charges
are payable
Average
horse-
power
supplied
in year
after
correction
for power
factor
Cost of
power
pur-
chased
Share of operating
Operating,
main-
tenance
and
adminis-
trative
expenses
Interest
(including
exchange)
Essex
Water heater load.
Etobicoke twp
Water heater load.
Exeter
Water heater load.
Fergus
Water heater load.
Fonthill
Water heater load.
Forest
Water heater load.
Gait
Water heater load.
Georgetown
Water heater load.
Glencoe
Water heater load.
Goderich
Water heater load.
$ c.
35.00
29.00
38.00
35' 00
34.00
48.00
27.66
35.00
58.00
42.00
Granton
Water heater load
Guelph
Water heater load
Hagersville
Hamilton
Water heater load
Harriston
50.00
27.00
31.00
23.50
Harrow
Water heater load
Hensall
Hespeler
Water heater load
Highgate
Water heater load
Humberstone
44.00
40.00
50.00
29.00
Ingersoll
Water heater load
Jarvis
Kingsville
Water heater load
Kitchener
Water heater load
Lambeth
Water heater load
46.00
28.00
28.00
38.00
38.00
27.00
42.00
$ c.
35.00
28.00
38.00
35 '00
36.00
48.00
27.00
35.00
58.00
42 '00
50.00
28.00
31.00
24.50
44.00
38.00
50.00
29.00
48.00
28.00
28.00
38.00
38.00
27.00
42.00
$ c.
105,032.26
790,357.84
133, 7 14 .3 7
'211,972! 65
'29,584.77
124,794.14
1,425,076 '.37
' 326, 244. i 7
' "78,757.34
'361,661.44
23,491.47
1,844,3 16 .85
177,314.24
18,808,727.40
103,670.12
111,039.96
60,955.56
445,148.80
24,587.78
"84,994 '57
542,693.39
58,523.85
141.829.66
3,644,588.90
"33,398.95
316.9
0.8
3,039.1
35.7
389.2
1.9
636.1
2.8
112.2
1.5
309.4
0.9
5,510.5
9.0
970.2
1.9
159.9
0.4
950.4
8.2
56.2
0.3
7,122.3
17.4
550.8
76,884.1
186.2
277.5
319.
2,
133
1,712
1
62
0.
322.
1,968.7
3.6
148.6
405.3
4.3
14,083.7
59.9
97.3
1.3
$ c.
2,746.00
26,334
42
3,372
50
5,511
94
972
24
2,681
01
47,749
60
8,406
98
1,385
57
8,235
41
486
98
61,716
17
4,772
666,216
79
32
2,404
2,767
59
67
1,156
14,839
80
16
545
04
2,792
17,059
79
18
1,287
3,512
65
11
122,038
12
843
12
$ c.
2,655.15
*28.85
16,209.72
*981.61
4,272.46
*75 .12
6,012.23
*104.66
1,174.56
*50.39
4,205.40
*41.80
34,927.33
*259.20
8,535.53
*67.50
2,969.92
*23.07
11,719.07
*355.65
1,180.90
*16.40
45,760.52
*503.89
4,876.82
326,554.82
*4,811.89
4,644.08
3,213.73
*97.53
2,131.21
11,003.35
*49.54
946.45
*9 35
2,006^08
13,755.71
♦110.56
2,042.11
3,992.57
*167.05
79,336.20
*1,686.66
1,254.98
*53.90
$ c
5,229.58
40,476.31
6,612.97
10,565.22
"l',5 16. 93
6,127.95
71,957 .36
16,166.86
3,806.32
17',648'.27
1,136.40
93,407 .02
8,63d 07
963,113.90
5,073.95
5,542.91
2,964.91
22,744.66
1,192.07
' '4,346 '. 29
27,332.73
2,859.44
7,028.77
184,765.34
"l, 654. 89
*Heater costs written off in year to extent of revenue available from heater loads.
1934
HYDRO-ELECTRIC POWER COMMISSION
161
SYSTEM N.— COST OF POWER
Municipality as the Cost — under Power Commission Act — of Power supplied to it
reserve of the system and proportionately applied in reduction of such
Municipality; and the amount remaining to be credited or
supplied to it in the year ending October 31, 1933
costs and fixed charges
Renewals
Sinking
fund
Total
cost of
power
for year
Amount
appropriat-
ed from
contingency
reserve
and pro-
portionate-
ly applied
in reduc-
tion of such
cost
Amounts
charged
to each
municipality
in respect
of power
supplied
to it in
the year
Amounts
received
from
(or billed
against)
each
municipality
by the
Commission
Amounts remaining
to be credited
or charged to each
municipality
Credited
Charged
$ c.
915.22
5,719.02
1,224.86
1,910.22
227.20
1,234.36
10,343.20
2,956.63
' ' 85l"22
3.487 '41
238.54
13.451.78
1,544.50
129.735.34
989.34
1.000.12
646.48
3,248.52
239.94
o46.i7
4,200.09
576.99
1,283.00
26,433.13
305 '56
$ c.
992.01
7,229.59
1,267.80
2,002.54
271.09
1,202.54
13,009.86
'3.084 '62
769.72
3,456 '90
226.36
16,850 '69
1,652.23
170,356.44
989.05
1,054.37
593.77
4,067.06
236.14
"778.82
5,005.73
558.29
1,347.70
33,295.37
"316A9
$ c
12,537.96
28.85
95,969.06
981.61
16,750.59
75.12
26,002.15
104.66
4,162.02
50.39
15,451.26
41.80
177,987.35
. 259.20
39,150.62
67.50
9,782.75
23.07
44,547.06
355.65
3,269.18
16.40
231,186.18
503.89
21,481.41
2,255,976.82
4,811.89
14,101.01
13,578.80
97.53
7,493.17
55,902.75
49.54
3,159.64
9.35
10,570.15
67,353.44
110.56
7,324.48
17,164.15
167.05
445,868.16
1,686.66
4,375.04
53.90
$ c
1,109.15
10,636.85
' 1,362 '. 20
2,226.35
"392.70
1,082.90
19,286.75
"3,395 '.70
559.65
3.326.40
196.70
24, 928 '.05
1,927.80
269,094.35
971.25
,117.90
467.25
5,993.75
220.15
1,128.05
6,890.45
520.10
1,418.55
49,292.95
"340.55
$ c.
11,428.81
, 28.85
85,332.21
981.61
15,388.39
75.12
23,775.80
104.66
3,769.32
50.39
14,368.36
41.80
158,700.60
259.20
35,754.92
67.50
9,223.10
23.07
41,220.66
355.65
3,072.48
16.40
206,258.13
503.89
19,553.61
,986,882.47
4,811.89
13,129.76
12,460.90
97.53
7,025.92
49,909.00
49.54
2,939.49
9.35
9,442.10
60,462.99
110.56
6,804.38
15,745.60
167.05
396,575.21
1,686.66
4,034.49
53.90
$ c.
1 11,422.60
) 89,095.06
\ 15,264.86
\ 22,994.23
) 4,141.26
\ 15,280.61
159,384.50
35,014.74
9,536.79
40,149.12
2,878.32
^04,139.60
17,563.88
1,911,204.44
12,522.39
12,660.95
6,853.88
52,808.71
3,083.63
r
9,279.98
56,860.73
5,808.52
15,982.99
392,768.37
4,241.33
f
$ c.
2,781.24
321.55
870.45
424.70
290.62
102.52
2,850.17
134.79
70.34
152.94
$ c.
35.06
198.65
886.23
807.68
1,427.19
210.56
2,622.42
1,989.73
80,489.92
607.37
172.04
162.12
3,712.82
995.86
5,493.50
62
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
NIAGARA
Statement showing the amount chargeable (upon annual adjustment) to each
by the Commission; the amount appropriated from the contingency
cost; the amount received by the Commission from each
charged to each Municipality in respect of power
Municipality
Interim rates
per
horsepower
collected by
Commission
during year
To
Jan. 1
1933
To
Oct. 31
1933
Share of
capital cost
of system on
which
interest and
fixed charges
are payable
Average
horse-
power
supplied
in year
after
correction
for power
factor
Cost of
power
pur-
chased
Share of operating
Operating,
main-
tenance
and
adminis-
trative
expenses
Interest
(including
exchange)
La Salle
Water heater load
Leamington
Water heater load
Listowel
Water heater load
London
Water heater load
London Railway
Commission
London twp
W T ater heater load
Long Branch
Water heater load
Lucan
Lynden
Markham
Water heater load
Merlin
Water heater load
Merritton
Water heater load
Milton
Water heater load
Milverton
Water heater load
Mimico
Water heater load
Mitchell
Water heater load
Moorefield
Mount Brydges
Water heater load
Newbury
New Hamburg
Water heater load
New Toronto
Water heater load
Niagara Falls
Niagara-on-the-Lake
Water heater load
Norwich
Water heater load
Oil Springs
ft c.
36.00
37.00
37!66
26'00
34.00
29.00
37.00
40.00
43.00
45.00
23.00
34^00
35.00
26.00
33.00
61.00
42.00
52.00
35.00
30.00
19.00
27.00
34.00
45.00
$ c.
35.00
$ c
63,407.59
37.00
37.00
26^00
343,897.76
261,715^70
7,053', 406. 79
34.00
312,323.66
94,623.02
30.00
183,962.18
37.00
40.00
43.00
39,444.97
27,090.24
71,114.45
45.00
33,765.03
23.00
34' 00
578,017.16
165,314.16
35.00
26~00
90,993.40
486,775 '29
33.00
123,079.96
61.00
42.00
21,464.55
26,632.82
54.00
35.00
18,725.58
139,549.43
30.00
1,260,255.14
19.00
27.00
1,645,138.21
107,216.16
34.00
45^00
96,599.07
63,928.56
197.3
0.8
973.8
6.1
820.9
2.1
28,067.1
265.8
990.0
323.6
5.2
679.0
3.0
127.4
82.6
221.2
0.7
85.6
0.1
2,715.2
3.4
542.1
4.9
283.4
0.8
1,981.4
24.6
414.9
3.6
41.4
84.1
0.7
42.0
444.7
1.3
4,618.0
6.8
8,347.8
480.8
1.7
308.8
1.1
166.3
$ c.
1,709.64
8,438.18
7,iii '27
243' 207 .12
8,578.55
2,804.06
5,883
67
1,103
715
1,916
95
75
74
741
74
23,527
76
4,697
41
2,455
72
17,169
23
3,595
19
358
' 728
74
74
363
3,853
94
42
40,015
91
72,335
4,166
38
23
2,675
81
1,441.02
$ c.
1,683.75
*28.48
8,865.52
*234.37
9,882.39
*81.49
140,290.95
*7,180.59
11,590.42
2,895.13
*176.95
4,109.14
*89.22
1,627.71
999 . 24
3,254.53
*29.08
1,313.44
*4.74
11,735.69
*81.24
6,256.99
*181.04
2,899.96
*29.47
10,271.61
*660.21
3,837.35
*123.64
1,042.21
1,261.12
*29.16
754.55
3,814.43
*45.45
27,946.31
*200.99
29,559.54
3,685.10
*47.27
2,899.68
*39.24
1,902.73
$
3,183
c .
3H
17,118.95
13,026
69
359,353
94
15,368.06
4,799.64
9,491
13
1,931
1,316
3,556
29
26
29
1,645
53
30,552
92
8,033
10
4,435
33
24,960.35
6,126
32
1,030
1,328
55
59
911
6,924
17
37
63,546
56
86,261
5,562
49
60
4,785
58
3,108
52
*Heater costs written off in year to extent of revenue available from heater loads.
1934
HYDRO-ELECTRIC POWER COMMISSION
63
SYSTEM
A 7 .— COST OF POWER
Municipality as the Cost — under Power Commission Act — of Power supplied to it
reserve of the system and proportionately applied in reduction of such
Municipality; and the amount remaining to be credited or
supplied to it in the year ending October 31, 1933
costs and fixed charges
Renewals
Sinking
fund
Total
cost of
power
for year
Amount
appropriat-
ed from
contingency
reserve
and pro-
portionate-
ly applied
in reduc-
tion of such
cost
Amounts
charged
to each
municipality
in respect
of power
supplied
to it in
the year
Amounts
received
from
(or billed
against)
each
municipality
by the
Commission
Amounts remaining
to be credited
or charged to each
municipality
Credited Charged
$ c.
540.14
$ c.
596.79
3,129.55
3,270.99
2,252.24
2,452.36
49,470.11
64,147.08
2,701.67
767.50
2,934.27
877.96
1,390.91
1,694.69
333.66
241.56
578.41
367.77
254.75
658.74
332.25
325.40
3,427.03
5,139.63
1,393.33
1,544.91
787.16
853.38
3,298.60
4,411.60
1,000.38
1,142.64
237 57
229.86
210.71
249.51
194.16
1,201 68
181.53
1,308.98
9,556.14
11,593.48
8,600.00
682.26
14,314.55
955.69
830.80
905.91
616.25
613.22
$ c
7,713.70
28.48
40,823.19
234.37
34,726.95
81.49
856,469.20
7,180.59
41,172.97
12,144.29
176.95
22,569.54
• 89.22
5,364.38
3,527.56
9,964.71
29.08
4,358.36
4.74
74,383.03
81.24
21,925.74
181.04
11,431.55
29.47
60,111.39
660.21
15,701.88
123.64
2,879.78
3,797.82
29.16
2,405.35
17,102.88
45.45
152,658.40
200.99
211,070.96
15,051.88
47.27
12,097.78
39.24
7,681.74
$ c.
1 690.55
3,408.30
2,873.15
98,234.85
3,465.00
1,132.60
2,376.50
445.90
289.10
774.20
299.60
9,503.20
1,897.35
991.90
6,934.90
1,452.15
144.90
294.35
147.00
1,556.45
16,163.00
29,217.30
1,682.80
1,080.80
"582.05
%
c.
7,023
15
28
48
37,414
89
234.37
31,853
80
81
49
758,234.35
7,180
59
37,707
97
11,011.69
176.95
20,193.04
89.22
4,918.48
3,238.46
9,190.51
29.08
4,058.76
4.74
64.879.83
81.24
20,028.39
181.04
10,439.65
29.47
53,176.49
660.21
14,249.73
123.64
2,734.
3,503.47
29.16
2,258.35
15,546.43
45.45
136,495.40
200.99
181,853.66
13,369.08
47.27
11,016.98
39.24
7,099.69
$ c.
7,155.87
37,255.70
31,231.18
757,905.02
29,374.36
11,466.99
20,900.40
4,832.79
3,386.21
9,763.12
14,177.53
2,562.95
3,641.02
2,308.89
16,031.81
142,537.58
163,448.92
13,349.55
10,835.511
7,678.521
$ c
104.24
278.35
618.14
147.75
543.53
108.39
50.54
439.93
5,841.19
578.83
393.56
704 . 1 1
7,509.92
8,333.61
85.69
103.28
719.66
1,119.83
251.62
195.89
195.84
171.93
18,404.74
66.80
220.71
164
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
NIAGARA
Statement showing the amount chargeable (upon annual adjustment) to each
by the Commission; the amount appropriated from the contingency
cost; the amount received by the Commission from each
charged to each Municipality in respect of power
Municipality
Interim rates
per
horsepower
collected by-
Con! mission
during year
To
Jan. 1
1933
To
Oct. 31
1933
Share of
capital cost
of system on
which
interest and
fixed charges
are payable
Average
horse-
power
supplied
in year
after
correction
for power
factor
Cost of
power
pur-
chased
Share of operating
Operating,
main-
tenance
and
adminis-
trative
expenses
Interest
(including
exchange)
Otterville
Water heater load
Palmerston
Paris
Water heater load
Parkhill
Petrolia
Water heater load
Plattsville
Point Edward
Water heater load
Port Colborne
Water heater load
Port Credit
Water heater load
Port Dalhousie . .
Water heater load
Port Dover
W 7 ater heater load
Port Rowan
Port Stanley
Water heater load
Preston
W T ater heater load
Princeton
Queenston
Richmond Hill
Water heater load
Ridgetown
Water heater load
Riverside
Water heater load
Rockwood
Rodney
Water heater load
St. Catharines
Water heater load
St. Clair Beach
Water heater load
St. George
St. Jacobs
Water heater load
$ c
43.00
40.00
28.00
62.00
40.00
62.00
40.00
28.00
32^00
30* 00
40.00
70.00
40.00
27.00
55^00
29.00
38.00
38.00
33.00
45 00
45.00
21.50
38' 00
40.00
32.00
$ c.
45.00
$ c.
29,556.65
40.00
28.00
142,824.08
297,845.33
62.00
40.00
66,838.16
294,973.29
55.00
40.00
25,549.83
181,434.32
29.00
33! 00
30 '00
326,027.87
146,493 !j>i
125. 066! 91
40.00
103,652.03
62.00
40.00
34,239.84
117,916.25
27.00
50'00
29.00
36.00
590,103.45
'4 1,708' 06
19,215.98
87,579.54
38.00
33.00
42.00
45.00
138,133.11
365,935 .70
"33,812 .94
51.045.63
23.00
38 '00
1,677,014.61
"26. 701 .07
42.00
32.00
46,499.31
44.483.51
74.4
0.2
426.0
1,141.4
6.5
123.6
841.4
1.7
58.
598
1,236
1
509
8
478
2
308.0
0.4
64.8
354
2
2,317.5
1
108
80.5
285.9
2.8
416.9
3.0
,109.9
13.6
90.6
126.0
7,787
7
73
139
150
0.6
$ c.
644.69
3,691
9,890
38
46
1,071.02
7,290.91
504
5,186
31
12
10,712
79
4,411
45
4,147
17
2,668
88
561
3,075
51
28
20,081
61
940.17
697.55
2.477.38
3,612
52
9,617
52
785
1,091
07
$2
67,483
.73
639
49
1,207
1,301
06
51
$ c.
1,168.30
♦9.62
5,913.61
7,543.94
*190.13
2,503.14
8,812.17
*65.35
1,032.45
7.474.57
♦11.46
6,882.69
♦51.43
5,391.31
♦285.77
4,034.79
♦77.96
2,677
♦14
1,212
3,691
♦80 . 1 1
14,367.80
♦48.12
1,689.74
598 . 73
1,570.56
♦87.83
4,687.34
*116.71
7,745.21
♦470.72
1,077.30
2,049.76
♦4.93
35,020.25
♦187.36
786.90
♦4.05
1,844.40
1,550.46
♦21.31
$ c.
1,448.44
7,066.50
15,034.92
3,210.62
14,516.75
1,235.66
9,113.60
16,591.23
' 7,403 '. 53
"6,348! 79
5,172.47
1,660.56
5,841.61
29,674.03
' 2,062 '. 55
983.37
4,419.89
6,856.71
18,306.73
1,657.39
2,506.29
87,042.16
"l'.322.23
2,308.17
2.228.10
♦Heater costs written off in year to extent of revenue available from heater loads.
934
HYDRO-ELECTRIC POWER COMMISSION
65
SYSTEM
N.— COST OF POWER
Municipality as the Cost — under Power Commission Act — of Power supplied to it
reserve of the system and proportionately applied in reduction of such
Municipality; and the amount remaining to be credited or
supplied to it in the year ending October 31, 1933
costs and fixed charges
Renewals
Sinking
fund
Total
cost of
power
for year
Amount
appropriat-
ed from
contingency
reserve
and pro-
portionate-
ly applied
in reduc-
tion of such
cost
Amounts
charged
to each
municipality
in respect
of power
supplied
to it in
the year
Amounts
received
Amounts remaining
from
to be credited
(or billed
or charged to each
against)
municipality
each
municipality
by the
,
Commission
Credited Charged
$ c.
294.31
1,273.91
2,187.44
753.65
2,690.79
266.98
1,488.24
2,478.68
1, 177^55
932.22
939.88
384.23
1,057.82
4,211.53
'408.87
133.20
682.53
$ c.
284.35
1,346.44
2,724.65
658.62
2,802.76
248.05
1,694.76
2,987.48
1,358 '. 93
1 ,136 .30
980.66
337.23
1,114.59
5,374.28
"400.05
173.33
818.35
1,217.79
1,303.77
3,176.57
3,454.10
326.39
513.28
323.35
492.39
9,952.14
14,827.83
246.75
254.61
419.20
366.12
439.41
414.21
$
c.
3,840
09
9
62
19,291
84
37,381
41
190
13
8,197
05
36,113
38
65
35
3,287
45
24,957
29
11
46
39,652
87
51
43
19,742
77
285
77
16,599
27
77
96
12,439
76
14
76
4,155
82
14,780
69
80
11
73,709
25
48
12
5,501
38
2,586
18
9,968
71
87
83
17,678
13
116
71
42,300
13
470
72
4,169
50
6,653
54
4
93
214,326
11
187
36
3,249
98
4.05
6,218
24
5,860
40
21
31
$ c.
260.40
1,491.00
3,994.90
432.60
2,944.90
203 . 70
\ 2,094.75
4,327.05
1,781.85
1,675. io
1,078.00
226.80
1,242.15
1 8,111.25
"379 '.75
281.75
\ 1,000.65
/
1,459.15
3,884.65
317.10
\ 441.00
27,257.65
258.30
487.55
525.70
$ c.
3,579.69
9.62
17,800.84
33,386.51
190.13
7,764.45
33,168.48
65.35
3,083.75
22,862.54
11.46
35,325.82
51.43
17,960.92
285.77
14,924.17
77.96
11,361.76
14.76
3,929.02
13,538.54
80.11
65,598.00
48.12
5,121.63
2,304.43
8,968.06
87.83
16,218.98
116.71
38,415.48
470.72
3,852.40
6,212.54
4.93
187,068.46
187.36
2,991.68
4.05
5,730.69
5,334.70
21.31
$ c
3,421 04
17,470.53
33,035.85
7,851.52
35,558.87
3,342.15
24,500.75
36,635.66
17,418.80
14,812.26
12,651.82
4,223.02
14,639.11
64,424.94
5,642.45
2,393.63
10,774.90
5,946.36
4,959.98
87.07
2,325 04
258.40
1,626.75
1.258.41
1,275.30
294.00
1,020.46
520.82
89.20
1,719.01
41.96
103.47
215.67
$ c.
168 27
330 31
540 . 79
827.89
189.87
1,221.18
732.20
388.35
5,056.45
109.04
396.03
166
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
NIAGARA
Statement showing the amount chargeable (upon annual adjustment) to each
by the Commission; the amount appropriated from the contingency
cost; the amount received by the Commission from each
charged to each Municipality in respect of power
Municipality
Interim rates
per
horsepower
collected by
Commission
during year
To
Jan. 1
1933
To
Oct. 31
1933
Share of
capital cost
of system on
which
interest and
fixed charges
are payable
Average
horse-
power
supplied
in year
after
correction
for power
factor
Cost of
power
pur-
chased
Share of
operating
Operating,
main-
tenance
Interest
and
(including
exchange)
adminis-
trative
expenses
St. Marys
Water heater load
St. Thomas
Water heater load
Sandwich
Water heater load
Sarnia
Water heater load
Scarboro twp
Water heater load
Seaforth
Simcoe
Water heater load
Springfield
Water heater load
Stamford twp
Stouffville
Water heater load
Stratford
Water heater load
Strathroy
Water heater load
Sutton
Tavistock
Tecumseh
Water heater load
Thamesford
Water heater load
Thamesville
Water heater load
Thedford
Thorndale
Thorold
Water heater load
Tilbury
Water heater load
Tillsonburg
Water heater load
Toronto
Water heater load
Toronto twp
Water heater load.
Walkerville
Water heater load.
$ c
34.00
$ c
34.00
28.00
32.00
28.00
32.00
34.00
32' 00
34.00
32'00
35.00
31.00
35.00
31.00
48.00
48.00
21.00
47.00
21.00
46.00
30.00
30.00
34.00
34.00
60.00
36.00
37.00
55.00
37.00
37.00
40.00
40.00
40.00
42.00
72.00
65.00
25.00
72.00
65.00
25.00
38.00
33.00
38.00
33.00
26.10
32.00
28.00
26.10
32.00
28.00
$ c.
381,531.43
,400,461.44
871,576.59
2,180,312.41
778,069 . 1 1
141,261.98
401,859.70
32,461.64
323,184.74
66,998.67
1,771,628.35
259,714.56
75,446.90
147,072.54
99,154.83
50,370.02
5 1,504 '85
39,165.84
21,828.02
406,622.06
122,347.31
245,130.88
62,399,625 24
429,947 '.25
1,95 8,828 '80
1,287
1
5,477
79
2,795
23.0
7,106.4
14.6
2,609.8
22.5
447.4
1,457.0
3.2
74.7
0.2
1,640.4
177.2
0.4
6,570.9
29.9
886.1
3.3
166.6
468.1
281.8
2.4
151.0
0.3
158.5
0.1
71.0
42.3
1,786.1
2.0
364.6
0.5
803.8
1.7
243,637.2
491.7
1,553.1
14.8
6,937.1
53.2
$ c.
11,159.91
47,463
65
24,223
29
61,578
40
22,614
45
3,876
12,625
81
20
647
29
14,214
1,535
40
47
56,938
18
7,678
24
1,443
4,056
2,441
62
19
85
1,308
45
1,373
43
615.23
366.54
15,476.92
3,159
33
6,965
09
2,111,165
76
13,457
93
60,111
40
$ c.
14,714.42
*43.81
33,649.95
*2,260.84
17,556.07
♦749.43
53,006.87
♦484.50
15,956.34
♦638.37
4,629.84
9,399.93
*97.05
1,147.86
*10. 03
6,851.89
2,659.25
*18.38
47,126.61
*908 . 42
6,659.11
♦107.20
2,942.92
4,646.14
2,617.52
♦92.30
2,072.47
♦12.46
2,090.76
♦4.04
1,634.08
1,041.78
9,193.55
♦51.32
4,213.01
♦19.71
6,515.49
♦57.62
,074,540.53
♦13,072.83
12,364.36
♦449.57
37,531.72
♦1,572.22
$ c.
19,048.75
71,202
95
43,669
04
109,277
50
39,302
60
6,932
20,434
30
97
1,568
02
17,050
3,312
66
10
89,167
37
13,015
23
3,693
7,322
4,921
38
64
60
2,491
05
2,554
60
1,884
1,039
21,151
65
47
01
6,032
63
12,217
02
3,177,443
27
21,873
62
98,584
12
♦Heater costs written off in year to extent of revenue available from heater loads.
1934
HYDRO-ELECTRIC POWER COMMISSION
167
SYSTEM
N.—COST OF POWER
Municipality as the Cost — under Power Commission Act — of Power supplied to it
reserve of the system and proportionately applied in reduction of such
Municipality; and the amount remaining to be credited or
supplied to it in the year ending October 31, 1933
costs and fixed charges
Total
cost of
power
for year
Amount
appropriat-
ed from
contingency
reserve
and pro-
portionate-
ly applied
in reduc-
tion of such
cost
Amounts
charged
to each
municipality
in respect
of power
supplied
to it in
the year
Amounts
received
from
(or billed
against)
each
municipality
by the
Commission
Renewals
Sinking
fund
Amounts remaining
to be credited
or charged to each
municipality
Credited
Charged
$ c.
3,052.66
$ c.
3,552.34
$ c.
51,528.08
43.81
175,136.37
2,260.84
100,872.21
749.43
262,320.98
484.50
91,032.59
638.37
17,967.88
49,286.62
97.05
4,009.00
10.03
42,617.31
8,761.86
18.38
222,636.93
908.42
31,885.03
107.20
9,577.71
18,653.00
11,823.91
92.30
6,800.15
12.46
6,951.53
4.04
4,959.85
2,904.90
52,080.27
51.32
15,646.86
19.71
30,056.62
57.62
7,330,271.64
13,072.83
54,988.39
449.57
. 229,290.91
1,572.22
$ c.
\ 4,507.65
$ c.
47,020.43
43.81
155,965.12
2,260.84
91,087.96
749.43
237,448.58
484.50
81,898.29
638.37
16,401.98
44,187.12
97.05
3,747.55
10.03
36,875.91
8,141.66
18.38
199,638.78
908.42
28,783.68
107.20
8,994.61
17,014.65
10,837.61
92.30
6,271.65
12.46
6,396.78
4.04
4,711.35
2,756.85
45,828.92
51.32
14,370.76
19.71
27,243.32
57.62
6,477,541.44
13,072.83
49,552.54
449.57
205,011.06
1,572.22
$ c.
1 44,964.58
1 159,817.15
{ 92,811.38
\ 248,806.30
/
\ 86,602.88
16,085.54
) 46,479.50
\ 3,693.79
/
35,400.11
\ 8,409.03
\ 203,303.57
/
\ 31,023.05
/
9,499.60
17,680.64
\ 10,801.42
\ 6,208.10
/
\ 6,758.77
f
5,208.48
2,813.89
1 45,918.60
/
) 14,226.27
\ 27,331.67
16,371,763.17
\ 51,474.89
j 201, 601. 30
$ c.
$ c.
2,099.66
1,591.19
973.99
10,873.22
4,066.22
10,034.36
12,785.46
\ 19,171.25
J
7,250.61
8,173.20
\ 9,784.25
/
18,061.22
20,396.99
\ 24,872.40
/
5,912.34
7,246.86
\ 9,134.30
1,206.86
1,322.07
3,707.44
1,565.90
1 5,099.50
316.44
3,119.08
2,195.33
333.45
312.38
1 261.45
/
63 79
1,688.47
2,811.89
641.14
5,741.40
\ 620.20
1,475 80
613.81
248.99
2,756.37
2,132.17
504.99
665.99
13,178.90
16,225.87
\ 22,998.15
{' 3,101.35
2,117.31
2,415.14
763.89
733.90
1,375.87
942.75
583.10
1,638.35
\ 986.30
1 528.50
1,252.16
900 . 19
128 49
452.35
475.83
76 01
357.95
497.13
57.04
38.36
447.76
484.98
1 554.75
439.94
385.95
214.58
3,638.10
248.50
148.05
) 6,251.35
/
242.53
2,620.69
1,086.55
1,155.34
\ 1,276.10
164.20
30.73
2,067.60
2,291.42
{ 2,813.30
1852,730.20
/
\ 5,435.85
| 24,279.85
398,390.06
568,732.02
118,851.10
1,472.78
3,325.46
3,967.02
14,930.93
18,132.74
4,981 98
68
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
NIAGARA
Statement showing the amount chargeable (upon annual adjustment) to each
by the Commission; the amount appropriated from the contingency
cost; the amount received by the Commission from each
charged to each Municipality in respect of power
Municipality
Interim rates
per
horsepower
collected by
Commission
during year
To
Jan. 1
1933
To
Oct. 31
1933
Share of
capital cost
of system on
which
interest and
fixed charges
are payable
Average
horse-
power
supplied
in year
after
correction
for power
factor
Cost of
power
pur-
chased
Share of
operating
Operating,
main-
tenance
Interest
and
(including
adminis-
exchange)
trative
expenses
Wallaceburg
Water heater load.
Wardsville
Waterdown
Waterford
Water heater load.
Waterloo
Water heater load
Watford
Water heater load
Welland
W 7 ater heater load
Wellesley
West Lome
Weston
Water heater load
Wheatley
Water heater load
Windsor
Water heater load
Woodbridge
W 7 ater heater load
Woodstock
Water heater load
Wyoming
York East twp. . . .
Water heater load
York North twp . . .
Water heater load
Zurich
$ c.
36.00
60.00
34.00
32.00
27.00
55.00
23' 00
45.00
40.00
28.00
51.00
28.00
35.00
27.00
54.00
32.00
32.00
62.00
$ c.
36.00
62.00
32.00
32.00
27.00
55.00
24.00
50.00
40.00
27.00
$ c.
536,888.73
15,388.76
59,051.71
108,813.44
779,764.29
81,608.70
805" 460 .13
42,384.44
33,606.54
624,411.23
50.00
28.00
35.00
27.00
'56.00
32.00
32.66
'62.00
Toronto Transportation Comm
Sandwich, Windsor and Amherst-
burg Railway Co
Windsor, Essex and Lake Shore
Railway Association
58,482.83
5 ,'614,408. 38
"90,450.77
1,197,647 '85
"28,007 .53
1,255,879.25
"718',868'.37
' "37.688.IO
93,886.13
753,852.03
5,306.50
1,599.1
1.5
31.4
200.3
376.4
0.6
2,972.8
19.2
185.4
0.4
3,578.5
18.8
104.3
99.7
2,480.3
24.0
120.3
0.7
19,926.6
148.7
292.9
0.7
4,543.0
21.8
61.2
4,883.1
14.0
2,490.9
29.9
70.0
335.8
2,617.5
$ c.
13,856.53
272.09
1,735.64
3,261.58
25,759.92
1,606.53
31, 008 .43
903.78
863.92
21,492.30
1,042.42
172,668 .05
" 2,538.04
39,366.02
"530.31
42,313.05
21,584. i6
606.56
2,909.78
22,681.19
$
15,236.
*56.
712.
1,517
2,570
*18
18,102
*554.
2,848
*20
15,801
*463
1,775
1,309.
13,060.
*654.
1,755.
*37.
105,468.
*4,368.
2,415.
*24.
26,888.
*628.
978.
48,399.
*451.
19,312.
*862.
1,622.
3,023.
14,376
106
c.
82
18
64
32
68
95
97
48
75
31
84
42
05
62
95
41
.51
.37
.55
81
68
03
82
12
50
06
97
73
06
06
24
72
18
$ c.
26,540.09
745.50
2,939.41
5,478.83
39,525
10
3,973
75
41,559
71
2,051
1,591
31,721
10
62
02
2,846
46
282,389
.10
4,513
.01
60,715
.17
1,358
64,534
.50
.53
36,609.90
1,799.67
3,952.48
38,109.48
182.99
*Heater costs written off in year to extent of revenue available from heater loads.
1934
HYDRO-ELECTRIC POWER COMMISSION
69
SYSTEM
N.—COST OF POWER
Municipality as the Cost — under Power Commission Act — of Power supplied to it
reserve of the system and proportionately applied in reduction of such
Municipality; and the amount remaining to be credited or
supplied to it in the year ending October 31, 1933
costs and fixed charges
Renewals
Sinking
fund
Total
cost of
power
for year
Amount
appropriat-
ed from
contingency
reserve
and pro-
portionate-
ly applied
in reduc-
tion of such
cost
Amounts
charged
to each
municipality
in respect
of power
supplied
to it in
the year
Amounts
received
from
(or billed
against)
each
municipality
by the
Commission
Amounts remaining
to be credited
or charged to each
municipality
Credited
Charged
$ c.
4,779.30
166.00
488.39
880 . 73
5,736.44
840.96
5,174'61
426.67
304.38
4,355.10
626.61
42,704.62
' 764^75
8,859.81
' 294^00
8,063.15
5,325.23
' 424 '89
735.59
5,855.03
79.56
$ c.
5,076.84
150.35
549.40
1,010.39
7.138.18
791.71
7,191.72
408.68
318.18
5,681.01
572.56
51,956.58
846 . 70
10,966.95
272.86
11,453.87
6,664.05
"37l'64
867.48
6,997.19
55.85
$ c.
65,489.58
56.18
2,046.58
7,230.16
13,202.21
18.95
96,262.61
554.48
10,061.70
20.31
100,736.31
' 463.42
5,565.28
4,387.72
76,310.38
654.41
6,843.56
37.37
655,186.90
4,368.81
11,078.18
24.03
146,796.77
628.12
3,434.17
174,763.66
451.97
89,496.07
862.06
4,824.82
11,488.57
88,019.61
424.58
$ c.
\ 5,596.85
J
109.90
701.05
1,317.40
\ 10,404.80
/
648.90
12,524.75
365.05
348.95
8,681.05
1 421.05
| 69,743. 10
1,025.15
15,900.50
"214.20
17,090.85
'8,718.15
245.00
1,175.30
9,161.25
$ c.
59,892.73
56.18
1,936.68
6,529.11
11,884.81
18.95
85,857.81
554.48
9,412.80
20.31
88,211.56
463.42
5,200.23
4,038.77
67,629.33
654.41
6,422.51
37.37
585,443.80
4,368.81
10,053.03
24.03
130,896.27
628.12
3,219.97
157,672.81
451.97
80,777.92
862.06
4,579.82
10,313.27
78,858.36
424.58
$
59,237
1,979
6,655
12,390
\ 72,215.25
10,470.22
88,102.59
5,249
4,089
69,926
43.17
126.04
486.71
1,037.1
49.34
50.81
1,642.37
475.00
269.47
2,353.09
1,244.66
359.71
$ c.
711.90
14,197.04
572.39
219.96
8,015.38
4,667.50
127.04
170
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
NIAGARA
Statement showing the amount chargeable (upon annual adjustment) to each
by the Commission; the amount appropriated from the contingency
cost; the amount received by the Commission from each
charged to each Municipality in respect of power
Rural power district
Share of
capital cost
of system on
which
interest and
fixed charges
are payable
Average
horse-
power
supplied
in year
after
correction
for power
factor
Cost of
power
pur-
chased
Share of operating
Operating,
main-
tenance
and
adminis-
trative
expenses
Interest
(including
exchange)
Acton R.P.D. — Erin, Esquesing
and Nassagaweya twps
Ailsa Craig R.P.D.— Lobo, McGil-
livray and Williams E. twps. . . .
Alvinston R.P.D. — Brooke twp. . .
Amherstburg R.P.D. — Anderdon,
Colchester N., Colchester S. and
Maiden twps
Water heater load
Aylmer R.P.D. — Bayham, Dere
ham, Dorchester N., Dorchester
S., Malahide and Yarmouth twps.
Water heater load
Ayr R.P.D. — Blenheim, Dumfries
N. and Dumfries S. twps
Baden R.P.D.— Blandford, Blen-
heim, Easthope N., Easthope S.,
Waterloo, Wellesley, Wilmot and
Zorra E. twps
Water heater load
Beamsville R.P.D. — Caistor, Clin-
ton, Gainsborough, Grimsby N.,
Grimsby S., Louth, Pelham and
Wainfleet twps
W T ater heater load
Belle River R.P.D.— Maidstone and
Rochester twps
Water heater load
Blenheim R.P.D.— Raleigh and
Harwich twps
Water heater load
Bond Lake R.P.D.— King, Mark-
ham, Vaughan, Whitchurch and
York N. twps
Water heater load
Bothwell R.P.D.— Aldborough.Ek-
frid, Mosa, Orford and Zone twps.
Brampton R.P.D. — Chinguacousy
and Toronto twps
Water heater load
Brant R.P.D.— Blenheim, Brant-
ford, Burford, Dumfries S., Oak-
land and Onondaga twps
Water heater load
Brigden R.P.D. — Moore and Som-
bra twps
$ c.
3,104.79
2,210.48
2,618.61
181,730.18
77,966.32
12,056.11
101,853.72
303,243.58
76,058.56
36,427.54
274,590.50
36,758.70
32,509.88
117,042.00
18,577.48
10.0
5.6
3.2
525.8
1.4
240.0
0.2
42.5
345.7
0.5
1,058.3
2.7
231.0
0.3
108.0
0.2
823.9
1.4
94.8
119.5
0.1
437.6
1.1
34.9
$ c.
86.65
48.52
27.73
4,556.18
2,079.64
368.28
2,995.56
9,170.38
2,001.68
935.84
7,139.26
821.46
1,035.49
3,791.89
302.421
$ c.
81.09
70.68
82.53
$ c.
156.29
109.76
125.04
4,264.16
*49. 38
9,029.26
2,048.85
*7.16
3,882.98
365.40
2,560.46
*16.61
611.57
5,149.91
9,265.10
*90.36
15,312.80
2,079.52
*11.00
3,785.01
934.53
*7.35
1,807.62
4,822.34
*52.29
13,748.87
1,158.35
1,448.57
*3 .57
1,802.30
1,652.62
3,884.31
*35.85
5,963.95
507.01
896.40
*Heater costs written off in year to extent of revenue available from heater loads.
1934
HYDRO-ELECTRIC POWER COMMISSION
171
SYSTEM
N.—COST OF POWER
Municipality as the Cost — under Power Commission Act — of Power supplied to it
reserve of the system and proportionately applied in reduction of such
Municipality; and the amount remaining to be credited or
supplied to it in the year ending October 31, 1933
costs and fixed charges
Renewals
Sinkinj
fund
Total
cost of
power
for year
Amount
appropriat-
ed from
contingency
reserve
and pro-
portionate-
ly applied
in reduc-
tion of such
cost
Amounts
charged
to each
municipality
in respect
of power
supplied
to it in
the year
Amounts
received
from
(or hilled
against)
each
municipality
by the
Commission
Amounts remaining
to be credited
or charged to each
municipality
Credited Charged
$ c
26.59
21.
32.69
1,630.36
686.82
95.90
834.73
2,482.64
659.53
325.10
2,299.97
355 . 70
248.18
881.40
206.79
$ c.
29.07
21.22
26.42
,724.45
733.70
111.61
947.76
2,808.43
717.77
344.51
2,592.08
351.74
299.17
1,074.61
183.04
$ c.
379.69
272.06
294.41
21,204.41\
49.38/
9,431. 99\
7.16/
1,552.76
12,488.42\
16.61]
39,039.35\
90.36/
9,243.51)
11.00/
4,347.601
7.35/
30,602.52
52.29
4,489.55
4,684.03\
3.57/
15,596.161
35.85/
2,095.66
$ c
35.00
19.60
11.20
1,840.30
840.00
148.75
1,209.95
3,704.05
808.50
378.00
2,883.65
331.80
418.25
,531.60
122.15
$ c
344.69
252.46
283.21
19,364.11
49.38
8,591.991
7.16/
1,404.01
11,278.471
16.61/
35,335.301
90.36/
8,435.01
11.00
3,969.601
7.35/
27,718.871
52.29/
4,157.75
4,265.781
3.57J
14,064.561
35.85/
1,973.51
$ c.
$ c.
344.69
see page
252.46
283.21
u
11
19,413.49
<<
8,599.15
a
1,404.01
'
11,295.08
a
35,425.66
«
8,446.01
«
3,976.95
"
27,771.16
a
4,157.75
«
4,269.35
a
14,100.41
a
1,973.51
a
185
11
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
NIAGARA
Statement showing the amount chargeable (upon annual adjustment) to each
by the Commission; the amount appropriated from the contingency
cost; the amount received by the Commission from each
charged to each Municipality in respect of power
Rural power district
Share of
capital cost
of system on
which
interest and
fixed charges
are payable
Average
horse-
power
supplied
in year
after
correction
for power
factor
Cost of
power
pur-
chased
Share of
operating
Operating,
main-
tenance
Interest
and
(including
adminis-
exchange)
trative
expenses
Burford R.P.D.— Brantford, Bur-
ford, Oakland, Townsend and
Windham twps
Caledonia R.P.D. — Ancaster, Bar-
ton, Binbrook, Caistor, Gland-
ford, Grimsby S. f Oneida, Onon-
daga and Seneca twps
Water heater load
Chatham R.P.D. — Chatham,
Dover E., Harwich and Raleigh
twps
Water heater load
Chippawa R.P.D. — Bertie, Crow-
land and Willoughby twps
Water heater load
Clinton R.P.D.— Goderich, Hay,
Hullett, Stanley and Tuckersmith
twps
Delaware R P.D. — Caradoc, Dela-
ware, Ekfrid, Lobo, London,
Southwold and Westminster twps.
Water heater load
Dorchester R P.D. — DorchesterN.,
Dorcheste S., London, Nissouri
E., Nissouri W., Oxford N., West-
minster and Yarmouth twps
Water heater load
Dresden R.P.D. — Camden, Chath-
ham Gore and Dawn twps
Water heater load
Drumbo R.P.D.— Blandford, Blen-
heim and Burford twps
Dundas R.P.D. — Ancaster, Bever-
ly, Flamboro W., Flamboro E.,
Glanford and Nelson twps
Water heater load
Dunnville R.P.D. — Canborough,
Dunn and Moulton twps
Dutton R.P.D.— Aldborough and
Dunwich twps
Water heater load
Elmira R.P.D.— Peel, Pilkington
and W 7 oolwich twps
Water heater load
% c.
46,086.19
79,953.94
114,530.24
21,842.34
42,317.15
80,489.11
90,019.08
13.270.82
30,099.88
139,904.37
12,202.61
38,951.00
25,736.54
154.3
274.2
0.8
403.4
2.4
95.5
0.1
116.2
277.8
2.2
290.0
0.1
35.9
0.4
75.6
538.5
0.7
42.0
118.4
0.1
79.9
0.2
$ c.
1,337.04
2,375.99
3,495.54
827.52
1,006.90
2,407.20
2.512.91
311.08
655.09
4,666.22
363.94
1,025.97
692.35
$ c
1,180.55
2,030.44
*26.41
2,763.43
*74.80
458.84
*2.52
1,504.21
,889.76
♦69.37
2,512.71
♦3.39
435.46
*17 . 13
1,092.08
2,339.99
♦18.75
208.10
1,320.52
♦3.64
572.51
♦6.89
$ c
2,333.79
4.044.07
5,776.23
1,111.51
2,098.24
4,037.79
4,474.21
661.61
1,469.23
7,137.19
622 52
1,957 84
1,298.99
♦Heater costs written off in year to extent of revenue available from heater loads.
934
HYDRO-ELECTRIC POWER COMMISSION
73
SYSTEM
N.—COST OF POWER
Municipality as the Cost — under Power Commission Act — of Power supplied to it
reserve of the system and proportionately applied in reduction of such
Municipality; and the amount remaining to be credited or
supplied to it in the year ending October 31, 1933
costs and fixed charges
Renewals
Sinking
fund
Total
cost of
power
for year
Amount
appropriat-
Amounts
Amounts
ed from
charged
received
Amounts remaining
contingency
to each
from
to be credited
reserve
municipality
(or billed
or charged to each
and pro-
in respect
against)
municipality
portionate-
of power
each
ly applied
supplied
municipality
in reduc-
to it in
by the
tion of such
cost
the year
Commission
Credited
Charged
383.25
653.55
890.38
143.70
397.87
646.98
769.87
125.55
300.45
1,030.96
101.75
347.08
225.85
429.78
741.57
1,059.41
195.59
402.64
745.37
844.42
126.79
289.68
1,279.03
113.35
367.75
242.17
5,664.41
9,845.62)
26.41/
13,984.99\
74.80/
2,737.16)
2.52/
5,409.86
9,727. 10\
69.37 f
11,114.12
3.39
1,660.49
17.13
3,806.53
16,453.39
18.75
1,409.66
5,019.16
3.64
3,031.87)
6.89/
540.05
959 . 70
1,411.90
334.25
406.70
972.30
1,015.00
125.65
264.60
1,884.75
147.00
414.40
279.65
5,lz4.36
,885. 92\
26.41
12,573.09
74.80
2,402.91
2.52
5,003.16
1, 754.80)
69.37/
10,099.12)
3.39/
1,534. 84\
17.13/
3,541.93
14,568.64)
18.75/
1,262.66
4,604.76)
3.64/
2,752.22)
6.89/
$ c.
$ c.
5,124.36
see page
8.912.33
«
12,647.89
a
2,405.43
u
5,003.16
u
8,824.17
a
10,102.51
a
1,551.97
see page
3,541.93
«
14,587.39
a
1,262.66
a
4,608.40
"
2,759.11
u
185
187
74
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
NIAGARA
Statement showing the amount chargeable (upon annual adjustment) to each
by the Commission; the amount appropriated from the contingency
cost; the amount received by the Commission from each
charged to each Municipality in respect of power
Rural power district
Share of
capital cost
of system on
which
interest and
fixed charges
are payable
Average
horse-
power
supplied
in year
after
correction
for power
factor
Cost of
power
pur-
chased
Share of operating
Operating,
main-
tenance
and
adminis-
trative
expenses
Interest
(including
exchange)
Elora R.P.D.— Garafraxa W\,
Nichol, Peel and Pilkington twps.
Water heater load
$ c.
32,226.45
95.0
0.1
181.0
0.1
266.4
0.2
32.5
173.5
114.7
0.3
79.1
633.2
1.9
376.7
2.5
188.9
16.9
341.5
1.9
323.5
1.0
$ c.
823.20
$ c.
837.64
♦3.63
1,266.55
♦3.47
3,204.10
*8.72
449.21
2,138.64
964.15
♦10.99
1,120.68
4,030.59
*50.85
2,582.65
*82.34
2,562.94
297.74
2,980.49
*73.46
3,092.39
♦31.82
$ c.
1,602.43
Essex R. P. D— Colchester N., Gos-
field N., Gosfield S., Maidstone,
Mersea, Rochester and Sandwich
S. twps
59,990.02
103,284.53
1,568.40
2,984.28
Water heater load
Exeter R.P.D.— Biddulph, Bosan-
quet, Hay, Hibbert, Stephen,
Tuckersmith and Usborne twps..
Water heater load
2,308.41
5,098.93
Forest R.P.D. — Adelaide, Bosan-
quet, Plympton, Warwick and
Williams W. twps
14,085.03
45,794.00
38,627.01
281.61
1,503.41
993.90
691.84
Gait R.P.D.— Beverly, Dumfries
N. and Dumfries S. twps
Georgetown R.P.D. — Chingua-
cousy, Erin and Esquesing twps.
Water heater load
2,337.00
1,929.60
Goderich R.P.D.— Ashfield, Col-
borne, Goderich and Wawanosh
W. twps
38,163.81
152,577.90
685.42
5,486.81
1,860.08
Grantham R.P.D. — Grantham and
Niagara twps
7,862.13
Guelph R.P.D. — Eramosa, Guelph,
Nassagaweya and Puslinch twps.
110,130.92
3,264.19
5,595.00
Haldimand R.P.D.— Cayuga N.,
Oneida, Rainham, Seneca and
Walpole twps
71,822.50
6,937.15
122,159.62
1,636.87
146.44
2,959.17
3,535.78
Harriston R.P.D. — Howick and
Minto twps
Harrow R.P.D.— Colchester N.,
Colchester S., Gosfield S. and
Maiden twps
342.15
6,088.41
Ingersoll R.P.D.— Dereham, Dor-
chester N., Nissouri E., Oxford
N., Oxford W., Zorra E. and Zorra
\Y. twps
Water heater load
103,967.57
2,803.19
5,200.00
♦Heater costs written off in year to extent of revenue available from heater loads.
1934
HYDRO-ELECTRIC POWER COMMISSION
75
SYSTEM
N.— COST OF POWER
Municipality as the Cost — under Power Commission Act — of Power supplied to it
reserve of the system and proportionately applied in reduction of such
Municipality; and the amount remaining to be credited or
supplied to it in the year ending October 31, 1933
costs and fixed charges
Renewals
Sinking
fund
Total
cost of
power
for year
Amount
appropriat
ed from
contingency
reserve
and pro-
portionate-
ly applied
in reduc-
tion of such
cost
Amounts
charged
to each
municipality
in respect
of power
supplied
to it in
the year
Amounts
received
from
(or billed
against)
each
municipality
by the
Commission
Amounts remaining
to be credited
or charged to each
municipality
Credited
Charged
% c.
293.66
522.75
$ c.
305.05
566.61
1,014.69
991.57
144.25
136.54
339.54
419.36
350.40
365.28
411.21
372.63
1,060.01
1,378.22
900.23
1,023.76
690.80
679.72
69.59
66.80
1,120.73
1,163.40
907.16
975.18
3,861. 98\
3.63/
6,908. 59\
3.47/
12,617.70
8.72
1,703.45
6,737.95
4,603. 33\
10.99/
4,450.02
19,817.76\
50.85/
13,365. 83\
82.34J
9,106.11
922.72
14,312. 20\
73.46/
12,977.921
31.82/
$ c.
332.50
633.50
932.40
113.75
607.25
401.45
276.85
2,216.20
,318.45
661.15
59.15
1,195.25
1,132.25
3,5.9.48
3.63
6,275.091
3.47(
11,685.301
8.72/
1,589.70
6,130.70
4,201.881
10.99/
4,173.17
17,601.56
50.85
12,047. 38\
82.34/
,444.96
863.57
13,116.95
73.46
11,845.67
45.671
31.82/
$ c.
$ c.
3,533.11
see page
6,278.56
a
11,694.02
u
1,589.70
a
6,130.70
a
4,212.87
a
4,173.17
«
17,652.41
«
12,129.72
U
8,444.96
a
863.57
U
13,190.41
a
11,877.49
a
187
76
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
NIAGARA
Statement showing the amount chargeable (upon annual adjustment) to each
by the Commission; the amount appropriated from the contingency
cost; the amount received by the Commission from each
charged to each Municipality in respect of power
Rural power district
Share of
capital cost
of system on
which
interest and
fixed charges
are payable
Average
horse-
power
supplied
in year
after
correction
for power
factor
Cost of
power
pur-
chased
Share of operating
Operating,
main-
tenance
and
adminis-
trative
expenses
Interest
(including
exchange)
Jordan R.P.D. — Grantham, Louth,
Pelham and Thorold twps
Water heater load
Keswick R.P.D. — Georgina, Gwil-
limbury N. and Gwillimbury E.
twps
Water heater load
Kingsville R.P.D.— Gosfield N.,
Gosfield S., Mersea and Romney
twps
Water heater load
Listowel R.P.D. — Elma, Grey,
Maryborough, Mornington, Peel,
Wallace and Wellesley twps
London R.P.D. — Delaware, Lobo,
London, Nissouri W. and West-
minster twps
Water heater load
Lucan R.P.D. — Biddulph, London,
McGillivray and Stephen twps.. .
Water heater load
Lynden R.P.D. — Ancaster, Bev-
erly, Brantford and Dumfries S.
twps
W^ater heater load
Markham R.P.D. — Markham,
Pickering, Scarboro, Uxbridgeand
Whitchurch twps
Water heater load
Merlin R.P.D. — Raleigh, Romney
and Tilbury E. twps
Milton R.P.D. — Esquesing, Nassa-
gaweya, Nelson and Trafalgar
twps
W 7 ater heater load
Milverton R.P.D.— Ellice, Elma,
Mornington and Wellesley twps..
Mitchell R.P.D.— Downie, Ellice,
Elma, Fullarton, Hibbert, Logan
and McKillop twps
W : ater heater load
Newmarket R.P.D. — Georgina,
Gwillimbury E., King, Scott, Ux-
bridge and Whitchurch twps.. . .
Water heater load
Niagara R.P.D. — Niagara and
Stamford twps
Water heater load
« c.
71,232.87
156,132.01
186,802.68
40,298.27
403,592.61
17,375.23
50,814.70
123,874.94
62,717.77
45,477.32
21,126.93
54,581.38
70,499.35
77,552.95
299.9
1.1
405.3
0.1
527.4
2.6
26.4
1,394.0
10.2
56.2
0.2
159.2
0.2
393.7
0.2
159.0
147.8
0.1
65.8
169.2
0.3
215.7
0.2
346.1
2.0
* c.
2,598.70
3,512.00
4,570.03
1,095.28
12,079.29
486.99
,379.50
3,411.49
1,377.77
1,280.72
570.17
1,466.15
,869.08
2,999.02
$ c.
1,447.62
*28.65
5,489.59
*4.22
4,156 67
*84.55
1,421.62
9,234.49
*274.40
526.26
*7.11
1,590.52
*7.64
3,251.39
*7.14
2,210.67
1,963.19
*3.94
613.19
1,399.70
*10.73
2,012.75
*6.83
2,077.39
*52.30
ft c.
3,686.50
7,737.29
9,224.31
2,019.93
20,384.83
864
M
2,529
42
6,224
77
3,111.42
2,291.91
1,058.43
2,726.50
3,521.46
3,974.55
*Heater costs written off in year to extent of revenue available from heater loads.
1934
HYDRO-ELECTRIC POWER COMMISSION
77
SYSTEM
N.—COST OF POWER
Municipality as the Cost — under Power Commission Act — of Power supplied to it
reserve of the system and proportionately applied in reduction of such
Municipality; and the amount remaining to be credited or
supplied to it in the year ending October 31, 1933
costs and fixed charges
Renewals
Sinking
fund
Total
cost of
power
for year
Amount
appropriat-
ed from
contingency
reserve
and pro-
portionate-
ly applied
in reduc-
tion of such
cost
Amounts
charged
to each
municipality
in respect
of power
supplied
to it in
the year
Amounts
received
from
(or billed
against)
each
municipality
by the
Commission
Amounts remaining
to be credited
or charged to each
municipality
Credited
Charged
$ c.
483.58
1,447.19
1,703.20
346.79
3,251.68
146.86
444.87
989.08
617.15
385.96
182.76
473.79
580.37
496.73
$ c.
641.42
1.496.7;
1.777.33
377.61
3,743.82
162.01
476.47
1,161.43
604.43
425.48
198.13
512.19
663.33
691.88
$ c
,857.82
28.65
19,682.85)
4.22/
21,431. 54\
84.55/
5,261.23
48,694. 11\
274.40/
2,186.44)
7.11
6,420.78)
7.64/
15,038.16
7.14
7,921.44
6,347.26
3.94
2,622.68
6,578.33)
10.73
8,646.99
6.83
10,239.57
52.30/
1,049
c.
65
1,418
55
1,845
90
442
4,879
40
00
196
70
557
20
1,377
95
556
517
50
30
230
592
30
20
754.95
1,211
.35
7,808.17)
28.65/
18,264.30)
4.22/
19,585.64)
84.55/
4,818.83
43,815.11)
274.40/
1,989.74)
7.11/
5,863.58
7.64
13,660.21
7.14
7,364.94
5,829.96)
3.94/
2,392.38
5,986.13)
10.73/
7,892.04)
6.83/
9,028.22)
52.30/
$
7,836
c.
82
18,268
52
19,670
19
4,818
83
44,089
51
1,996
85
5,871
22
13,667
35
7,364
94
5,833
90
2,392
38
5,996.86
7,898
87
9,080
52
$ c. $ c.
see page 187
see page
189
178
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
NIAGARA
Statement showing the amount chargeable (upon annual adjustment) to each
by the Commission; the amount appropriated from the contingency
cost; the amount received by the Commission from each
charged to each Municipality in respect of power
Rural power district
Share of
capital cost
of system on
which
interest and
fixed charges
are payable
Average
horse-
power
supplied
in year
after
correction
for power
factor
Cost of
power
pur-
chased
Share of operating
Operating,
main-
tenance
and
adminis-
trative
expenses
Interest
(including
exchange)
Norwich R.P.D.— Burford, Dere-
ham, Middleton, Norwich N.,
Norwich S., Oxford E. and Wind-
ham twps
Water heater load
Oil Springs R.P.D. — Brooke,
Dawn, Enniskillen and Euphemia
twps
Palmerston R.P.D. — Arthur,
Maryborough, Minto, Peel and
Wallace twps
Petrolia R.P.D.— Enniskillen ,
Moore, Plympton and Sarnia twps
Preston R.P.D.— Dumfries N.,
Guelph, Puslinch, Waterloo and
Woolwich twps
W^ater heater load
Ridgetown R.P.D.— Aldborough,
Harwich, Howard, Orford and
Rondeau Park twps
Water heater load
St. Jacobs R.P.D.— Peel, Waterloo,
Wellesley and W 7 oolwich twps. . . .
Water heater load
St. Marys R.P.D.— Blanshard,
Downie, Fullarton, Nissouri E.,
Nissouri W. and Usborne twps. . .
St. Thomas R.P.D.— Dunwich,
Southwold, Westminster and Yar-
mouth twps
Water heater load
Saltfleet R.P.D.— Barton, Bin-
brook, Grimsby N. and Saltfleet
twps
Water heater load
Sandwich R.P.D.— Anderdon, Col-
chester N., Maidstone, Sandwich
E., Sandwich W. and Sandwich S.
twps
Water heater load
Sarnia R.P.D. — Moore, Plympton
and Sarnia twps
Water heater load
$ c
76,245.00
15,976.46
16,763.38
8,745.06
239,163.10
95,655.14
71,027.26
65,182.98
127.738.17
264,433.70
265,738.12
167,396.36
241.6
0.6
41.6
50.0
25.3
849.0
1.2
244.9
1.1
237.6
0.2
185.4
455.2
3.2
875.3
1.3
874.4
2.4
493.7
2.6
2,093.51
360.47
433.26
219.23
7,356.76
2,122.11
2,058.84
1,606.53
3,944.40
7,584.65
7,576.86
4,278.01
$
c.
2,001
28
*20
88
464
54
615
21
245
56
5,318
*33
19
78
3,125
96
*48
79
1,828
*6
64
57
2,155
39
3,164
*99
90
59
6,093.66
*36.84
5,202
*75
.50
89
4,485
♦96
.74
.93
3,781.35
786.05
840 . 75
434.63
12,110.32
4,689.57
3,573.40
3,242.36
6,447.38
13,201.52
13,286.18
8,337.84
*Heater costs written off in year to extent of revenue available from heater loads.
934
HYDRO-ELECTRIC POWER COMMISSION
179
SYSTEM
N.—COST OF POWER
Municipality as the Cost — under Power Commission Act — of Power supplied to it
reserve of the system and proportionately applied in reduction of such
Municipality; and the amount remaining to be credited or
supplied to it in the year ending October 31, 1933
costs and fixed charges
Renewals
Sinking
fund
Total
cost of
power
for year
Amount
appropriat-
Amounts
Amounts
ed from
charged
received
Amounts remaining
contingency
to each
from
to be credited
reserve
municipality
(or billed
or charged to each
and pro-
in respect
against)
municipality
portionate-
of power
each
ly applied
supplied
municipality
in reduc-
to it in
by the
tion of such
cost
the year
Commission
Credited
Charged
660.00
154.00
149.52
79.05
,886.91
933.03
589.06
593.47
1,004.21
2,231.53
2,158.49
1,493.63
715.79
153.23
158.04
82.97
2,211.21
918.68
662.17
619.41
1,182.08
2,469.16
2,479.68
1,584.73
9,251.931
20.881
1,918.29
2,196.78
1,061.44
28,883. 39\
33.78/
11,789.35\
48.79/
8,712.11
6.57
8,217.16
15,742.97
99.59
31,580.52)
36.84/
30,703.71
75.89
20,179. 95\
96.93/
845.60
145.60
175.00
88.55
2,971.50
857 15
831.60
648.90
1,593.20
3,063.55
3,060.40
1,727.95
8,406.33
20.88
1,772.69
2,021.78
972.89
25,911.89
33.78
10,932.20
48.79
7,880. 51\
6.57/
7,568.26
14,149.77
99.59
28,516. 97\
36.84f
27,643.31)
75.89/
18,452. 00\
96.93f
$ c
$ c.
8,427.21
see page
1,772.69
a
2,021.78
a
972.89
u
25,945.67
a
10,980.99
u
7,887.08
a
7,568.26
»
14,249.36
"
28,553.81
u
27,719.20
«
18,548.93
a
189
180
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
NIAGARA
Statement showing the amount chargeable (upon annual adjustment) to each
by the Commission; the amount appropriated from the contingency
cost; the amount received by the Commission from each
charged to each Municipality in respect of power
Rural power district
Share of
capital cost
of system on
which
interest and
fixed charges
are payable
Average
horse-
power
supplied
in year
after
correction
for power
factor
Cost of
power
pur-
chased
Share of operating
Operating,
main-
tenance
and
adminis-
trative
expenses
Interest
(including
exchange)
Scarboro R.P.D. — Pickering, Scar-
boro and York N. twps
Water heater load
Seaforth R.P.D.— Hibbert, Hul-
lett, McKillop and Tuckersmith
twps
Simcoe R.P.D. — Charlotteville,
Townsend, Walpole, Windham
and Woodhouse twps
Water heater load
Stamford R.P D— Stamford and
Thorold twps
Stratford R.P.D.— Downie, East-
hope N., Easthope S. and Ellice
twps
Water heater load
Strathroy R.P.D.— Adelaide, Cara-
doc, Ekfrid, Lobo, Metcalfe and
Williams E. twps
Streetsville R.P.D.— Chingua-
cousy, Esquesing, Toronto and
Trafalgar twps
W^ater heater load
Tavistock R.P.D.— Easthope N.,
Easthope S., Ellice and Zorra E.
twps
Thamesville R.P.D.— Camden,
Chatham, Euphemia, Harwich,
Howard, Orford and Zone twps. .
Water heater load
Tilbury R.P.D.— Dover W\, Mer-
sea, Rochester, Romney, Tilbury
E., Tilbury W. and Tilbury N.
twps
Water heater load
Tillsonburg R.P.D.— Bayham,
Dereham, Dorchester S., Hough-
ton, Malahide, Middleton, Nor-
wich N., Norwich S. and Walsing-
ham N. twps
W 7 ater heater load
Wallaceburg R.P.D.— Chatham,
Dover E. and Sombra twps
Water load heater
$ c.
99,385.27
16,950.28
57,483.39
37,543.95
40,881.40
30,824.41
90,613.06
44,994.85
31,715.30
53,383.43
95,102.09
61,583.45
300.6
1.1
51.7
202.3
2.5
159.4
150.7
0.3
89.2
270.2
0.6
143.3
97.6
0.3
158.0
0.1
290.7
1.3
179.6
0.5
$
c.
2,604
76
447
99
1,752
97
1,381
24
1,305
85
772
94
2,341
34
1,241
73
845
72
1,369
10
2,518
98
1,556
28
1,677.34
*29.82
518.88
1,839.38
*83. 65
723.64
1,075.45
*9.14
1,085.28
3,067.42
*23.90
1,297.06
885.05
*10.92
1,566.46
*3.82
2,447.83
*46.45
1,872.84
♦19.57
$ c
4,982.47
847.97
2,917.91
1,934.38
2,054.35
1,537.58
4,513.87
2,246.02
1,588.71
2,672.49
4,700.37
3,042.59
*Heater costs written off in year to extent of revenue available from heater loads.
1934
HYDRO-ELECTRIC POWER COMMISSION
SYSTEM
N.—COST OF POWER
Municipality as the Cost — under Power Commission Act — of Power supplied to it
reserve of the system and proportionately applied in reduction of such
Municipality; and the amount remaining to be credited or
supplied to it in the year ending October 31, 1933
costs and fixed charges
Renewals
Sinking
fund
Total
cost of
power
for year
Amount
appropriat-
ed from
contingency
reserve
and pro-
portionate-
ly applied
in reduc-
tion of such
cost
Amounts
charged
to each
municipality
in respect
of power
supplied
to it in
the year
Amounts
received
Amounts remaining
from
to be credited
(or billed
or charged to each
against)
municipality
each
municipality
by the
Commission
Credited
Charged
$ c.
$ c.
$ c.
$ c.
$ c.
$ c.
$ c.
$ C.
827.51
937.54
11,029.621
29.82/
2,123.06
1,052.10
9,977.521
29.82/
1,942.11
10,007.34
1,942.11
see page
see page
189
148.85
159.37
180.95
191
458.38
532.52
7,501.161
83.65/
708.05
6793.11/
83.65/
6,876.76
a
«
252.73
337.90
4,629.89
557.90
4,071,99
4,071.99
a
"
306.03
374.77
5,116.451
9.14/
3,970.60
527.45
4,589.001
9.14/
3,658.40
4,598.14
a
a
282.79
292.01
312.20
3,658.40
u
«
817.72
856.54
11,596.89/
23.90/
5,588.60
945.70
10,651.191
23.90/
5,087.05
10,675.09
a
u
382.89
420.90
501.55
5,087.05
u
a
275.71
298.63
3,893.82/
10.92/
6,588.89/
3.82/
11,404.411
46.45/
7,611.431
19.57/
341.60
3,552.221
10.92/
6,035.891
3.82/
10,386.96/
46 45 r
3,563.14
a
a
476.33
504.51
553.00
6,039.71
u
u
842.21
895.02
1,017.45
10,433.41
u
it
556.02
583.70
628.60
6,982.831
19.57(
7,002.40
a
u
182
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
NIAGARA
Statement showing the amount chargeable (upon annual adjustment) to each
by the Commission; the amount appropriated from the contingency
cost; the amount received by the Commission from each
charged to each Municipality in respect of power
Rural power district
Share of
capital cost
of system on
which
interest and
fixed charges
are payable
Average
horse-
power
supplied
in year
after
correction
for power
factor
Cost of
power
pur-
chased
Share of operating
Operating,
main-
tenance
and
adminis-
trative
expenses
Interest
(including
exchange)
Walsingham R.P.D.— Charlotte-
ville, Houghton, Middleton, Wal-
singham N., Walsingham S. and
Windham twps
Water heater load
Walton R.P.D.— Grey, Hullett,
McKillop, Morris, Wawanosh E.
and Wawanosh W. twps
Water heater load
Waterdown R.P.D. — Flamboro E.,
Flamboro W. and Nelson twps.. .
Water heater load
Waterford R.P.D. — Townsend,
and Windham twps
Water heater load
Watford R.P.D.— Adelaide, Met-
calfe and Warwick twps
Welland R.P.D.— Bertie, Crow-
land, Humberstone, Moulton,
Pelham, Thorold, Wainfleet,
and Willoughby twps
W T ater heater load
Woodbridge R.P.D.— Albion.Chin-
guacousy, Etobicoke, King, Tor-
onto, Toronto Gore, Vaughan and
York N. twps
Water heater load
Woodstock R.P.D.— Blandford,
Blenheim, Burford, Oxford E.,
Oxford N., Oxford W., Zorra E.
and Zorra W. twps
Water heater load
Totals Municipalities
Water heater loads . . .
Totals — Rural Power Districts.
Water heater loads . . .
Totals — Companies
Totals — Local distribution sys-
tems
Water heater loads . . .
Non-operating capital
Grand total
60,798.60
35,873.12
203,660.56
45,907.50
8,749.66
262,740.63
165,290.75
137,723.61
144,023,104.06
7,289,267.28
45,468,930' 88
1,406,334.62
102,132.57
198,289,769.41
133
85
651
9
158
20
1,012
3
525
1
479
1
552,272.
1,851
23,605
76
197,579.
4,182.
19.
779,587.6
$ c
1,152.47
740.87
5,644.51
1,376.04
180.24
8,770.05
4,554.43
4,155.83
4,785,554.05
'204,543 '.91
1,712,065.60
36,243.07
6,738,406.63
$ c
1,692.29
*24.80
1,215.98
*4.83
4,376.74
*286.45
1,008.90
*9.36
273.29
7,933.46
*99.10
3,631.92
*63.68
2,868.08
*45.85
2,921,649.15
*52,502.48
190,563.18
*2,429.87
974,752.47
100,542.47
♦628.72
4,243,068.34
$ c.
2,980.25
1,759.75
10,195.13
2,325.73
431.75
13,324.10
,256.37
6,929.98
7,314,488.01
365,513 '99
2,399,216.15
72,329.47
10,151,547.62
*Heater costs written off in year to extent of revenue available from heater loads.
1934
HYDRO-ELECTRIC POWER COMMISSION
183
SYSTEM
N.—COST OF POWER
Municipality as the Cost — under Power Commission Act — of Power supplied to it
reserve of the system and proportionately applied in reduction of such
Municipality; and the amount remaining to be credited or
supplied to it in the year ending October 31, 1933
costs and fixed charges
Total
cost of
power
for year
Amount
appropriat-
ed from
contingency
reserve
and pro-
portionate-
ly applied
in reduc-
tion of such
cost
Amounts
charged
to each
municipality
in respect
of power
supplied
to it in
the year
Amounts
received
from
(or billed
against)
each
municipality
by the
Commission
Renewals
Sinking
fund
Amounts reman
to be credited
or charged to each
municipality
Credited
Charged
$ c.
646.45
$ c.
592.35
$ c.
7,063. 81\
24.80/
4,426.521
4.83/
23,888.02\
286.45/
5,508.51/
9.36/
1,058.31
34,410.87/
99.10/
19,412.12/
63.68/
16,336.80)
45.85/
$ c.
465.50
299.25
2,279.90
$ c.
6,598.31/
24.80/
4,127.27/
4.83/
21,608.12/
286.45/
4,952.71/
9.36/
985.51
30,868.52/
99.10/
17,572.52/
63.68/
14,658.20/
45.85/
$ c.
6,623.11
4,132.10
21,894.57
4,962.07
985.51
30,967.62
17,636.20
14,704.05
$ c.
see page
u
a
a
a
$ c.
191
363.79
346.13
u
1,762.59
1,909.05
a
371.57
426.27
555.80
72.80
3,542.35
1,839.60
«
88.49
1,981.39
84.54
2,401.87
«
1,417.98
1,551.42
u
1,105.60
1,277.31
1,678.60
u
1,003,146.46
1,317,126.56
17,341,964.231
52,502.48/
890,298.62/
2,429.87/
5,796,876.29
241,429.89/
628.72/
1,932,954.10
' 82,618.20
15,409,010.13/
52,502.48/
807,680.42/
2,429.87/
5,796,876.29
241,429.89/
628.72/
15,215,450.86
810,110.29
3,590,229.96
227,670.51
74,541.31
320,603.06
61,478.48
68,199.06
288,709.67
23,444.26
422,132.40
8,870.62
2,206,646. 33f
14,388. 10f
1,376,778.87
1,816,328.64
24,326,130.10
2,015,572.30
22,310,557.80
19,843,461.62
74,541.31
2,541,637.49
fWritten off to contingency reserve.
84
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
NIAGARA SYSTEM—
Statement showing the costs of distribution of power within each Rural Power
and the amounts remaining to be credited to certain Districts or charged
(by annual adjustment) of the actual costs
District and municipalities
comprised therein
Total capital cost of each district,
Provincial Government grant re-
ceived and applied thereagainst,
and the balance representing the
investment by the Commission
Total
capital
cost
Govern-
ment
grant
Com-
mission's
investment
Cost of
power
delivered
to districts
as shown
in "cost of
power"
table
preceding
Acton R.P.D. — Erin, Esquesing and Nassa-
gaweya twps
Ailsa Craig R.P.D.— Lobo, McGillivray and
Williams E. twps
Alvinston R.P.D. — Brooke twp
Amherstburg R.P.D. — Anderdon, Colches-
ter N., Colchester S., and Maiden twps. .
Aylmer R.P.D. — Bayham, Dereham, Dor-
chester N., Dorchester S., Malahide and
Yarmouth twps
Ayr R.P.D. — Blenheim, Dumfries N. and
Dumfries S. twps
Baden R.P.D.— Blandford, Blenheim, East-
hope X., Easthope S., Waterloo, Wellesley,
Wilmot and Zorra E. twps
Beamsville R.P.D. — Caistor, Clinton,
Gainsborough, Grimsby N., Grimsby S.,
Louth, Pelham and Wainfleet twps
Belle River R.P.D.— Maidstone and Ro-
chester twps
Blenheim R.P.D. — Raleigh and Harwich
twps
Bond Lake R.P.D. — King, Markham,
Vaughan, Whitchurch and York N. twps.
Bothwell R.P.D.— Aldborough, Ekfrid,
Mosa, Orford and Zone twps
Brampton R.P.D. — Chinguacousy and
Toronto twps
Brant R.P.D.— Blenheim, Brantford, Bur-
ford, Dumfries S., Oakland and Onondaga
twps
Brigden R.P.D. — Moore and Sombra twps
Burford R.P.D.— Brantford, Burford, Oak-
land, Townsend and Windham twps. . .
Caledonia R.P.D. — Ancaster, Barton, Bin
brook, Caistor, Glanford, Grimsby S.,
Oneida, Onondaga and Seneca twps
Chatham R.P.D.— Chatham, Dover E.
Harwich and Raleigh twps
Chippawa R.P.D. — Bertie, Crowland and
Willoughby twps
Clinton R.P.D.— Goderich, Hay, Hullett
Stanley and Tuckersmith twps
Delaware R.P.D. — Caradoc, Delaware, Ek
frid, Lobo, London, Southwold and West
minster twps
Dorchester R.P.D. — Dorchester N., Dor-
chester S., London, Nissouri E., Nissouri
\\\, Oxford N., Westminster and Yar-
mouth twps
$
c.
14,921
66
9,208
5,447
19
60
139,175
07
♦191,391
87
♦41,231
34
♦168,426
20
352,966
94
87,817
60
♦107,444
50
331,890
87
♦54,334
84
78,385
00
♦227,466
54,675
48
09
93,034
23
202,096
.52
258,017
.35
58,104
.36
126,143
.80
=225,463.84
*202,777.92
$ c.
7,460.83
4,604.10
2,723.80
69,502.03
93,840.30
20,580.18
83,853.79
170,410.90
43,832.64
52,732.90
165,945.43
26,835.40
39,192.50
112,622.33
27,337.54
46,517.11
100,802.33
129,008.68
29,049.30
62,133.13
111,784.97
$ c.
7,460.83
4,604.09
2,723.80
69,673.04
97,551.57
20,651.16
84,572.41
182,556.04
43,984.96
54,711.60
165,945.44
27,499.44
39,192.50
114,844.15
27,337.55
46,517.12
101,294.19
129,008.67
29,055.06
64,010.67
113,678.87
100,397.32 102,380.60
$ c.
344.69
252.46
283.21
19,413.49
8,599.15
1,404.01
11,295.08
35,425.66
8,446.01
3,976.95
27,771.16
4,157.75
4,269.35
14,100.41
1,973.51
5,124.36
8,912.33
12,647.89
2,405.43
5,003.16
8,824.17
10,102.51
Items marked ♦ include portions of transmission lines aggregating $44,995.90 used for
1934
HYDRO-ELECTRIC POWER COMMISSION
185
RURAL POWER DISTRICTS N.— RURAL OPERATING
District, the revenues collected from (or charged to) customers within each District,
to the Municipalities comprising certain other Districts upon ascertainment
in the year ending October 31, 1933
Distribution
costs and
fixed charges
Total
cost
Revenue
from
power
and light
customers
in each
district
Amounts i
'emainine:
Cost of
operation,
mainten-
ance and
adminis-
Interest
(including
exchange)
Renewal
charges
Obsoles-
cence
and
contin-
gencies
Sinking
fund
to be credited to
certain districts or
charged to the muni-
cipalities comprising
certain other
districts
tration
Credited
Charged
$ c.
363.43
$ c.
342.50
212.76
126.25
3,163.51
4,460.49
940 . 85
3,847.76
8,324.96
2,027.58
2,511.95
7,385.44
1,319.28
1,800.60
5,309.03
1,260.43
2,119.38
4,655.48
5,864.93
1,340.72
2,865.62
5,179.34
4,669.84
$ c.
295.48
183.55
108.92
2,725.81
3,775.46
810.27
3,305.17
6,942.95
1,746.20
2,127.54
6,371.59
1,124.90
1,553.42
4,535.79
1,087.40
1,828.44
4,006.55
5,059.80
1,156.56
2,434.69
4,430.46
3,986.24
$ c.
147.74
91.78
54.46
1,362.91
1,887.72
405 . 14
1,652.59
3,471.47
873.09
1,063.78
3,185.80
562.45
776.70
2,267.90
543 . 70
914.22
2,003.28
2,529.90
578.28
1,217.35
2,215.23
1,993.12
$ c.
77.79
48.32
28.67
718.47
1,013.03
213.68
873.87
1,890.69
460.48
570.50
1,677.32
299.62
408.94
1,205.74
286.26
481.34
1,057.31
1,331.99
304.49
650.82
1,176.29
1,060.58
$ c.
1,571.63
961.62
705.48
32,042.89
27,858.44
5,419.70
26,370.97
74,316.32
17,371.42
14,623.21
61,498.42
10,508.02
11,531.52
36,687.56
6,595.44
13,977.00
27,723.95
39,029.04
8,313.55
16,441.34
30,860.85
30,128.48
$ c.
1,320.29
887.13
509.05
35,200.71
29.452.53
4,144.44
23,050.86
75,426.87
18,957.35
17,018.78
66,163.80
9,997.89
10,070.38
31,473.27
5,402.89
13,597.80
25,038.94
38,880.56
8,287.66
15,169.53
30,609.57
30,551.38
$ c.
$ c
251.34
172.75
74.49
103.97
196.43
4,658.70
3,157.82
1,594.09
8,122.59
1,645.75
1,275.26
5,396.50
3,320.11
18,260.59
1,110.55
1,585.93
2,395.57
4,665.38
3,818.06
4,372.49
15,107.11
3,044.02
510.13
2,722.51
1,461.14
9,268.69
5,214.29
1,444.14
1,192.55
3,509.26
379.20
7,089.00
2,685.01
11,594.53
148.48
2,528.07
25.89
4,269.70
1,271.81
9,035.36
25.1.28
8,316.19
422.90
purposes of rural power districts.
86
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
NIAGARA SYSTEM—
Statement showing the costs of distribution of power within each Rural Power
and the amounts remaining to be credited to certain Districts or charged
(by annual adjustment) of the actual costs
District and municipalities
comprised therein
Total capital cost of each district,
Provincial Government grant re-
ceived and applied thereagainst,
and the balance representing the
investment by the Commission
Total
capital
cost
Govern-
ment
grant
Com-
mission's
investment
Cost of
power
delivered
to districts
as shown
in "cost of
power"
table
preceding
Dresden R.P.D. — Camden, Chatham Gore
and Dawn twps
Drumbo R.P.D. — Blandford, Blenheim and
Burford twps
Dundas R.P.D. — Ancaster, Beverly, Flam-
boro W., Flamboro E., Glanford and
Nelson twps
Dunnville R.P.D. — Canborough, Dunn and
Moulton twps
Dutton R.P.D. — Aldborough and Dunwich
twps
Elmira R.P.D.— Peel, Pilkington and Wool-
wich twps
Elora R.P.D.— Garafraxa W., Nichol, Peel
and Pilkington twps
Essex R.P.D.— Colchester N., Gosfield N.,
Gosfield S., Maidstone, Mersea, Rochester
and Sandwich S. twps
Exeter R.P.D. — Biddulph, Boanquet, Hay,
Hibbert, Stephen, Tuckersmith and Us-
borne twps
Forest R.P.D. — Adelaide, Bosanquet,
Plympton, Warwick and Williams W.
twps
Gait R.P.D.— Beverly, Dumfries N. and
Dumfries S. twps
Georgetown R.P.D. — Chinguacousy, Erin,
and Esquesing twps
Goderich R.P.D.— Ashfield, Colborne, God-
erich and Wawanosh W. twps
Grantham R.P.D. — Grantham and Ni-
agara twps
Guelph R.P.D. — Eramosa, Guelph, Nassa-
gaweya and Puslinch twps
Haldimand R.P.D. — Cayuga N., Oneida,
Rainham, Seneca and Walpole twps....
Harriston R.P.D. — Howick and Minto
twps
Harrow R.P.D. — Colchester N., Colchester
S., Gosfield S. and Maiden twps
Ingersoll R.P.D. — Dereham, Dorchester N.,
Nissouri E., Oxford N., Oxford W., Zorra
E. and Zorra W. twps
Jordan R.P.D. — Grantham, Louth, Pelham
and Thorold twps
Keswick R.P.D. — Georgina, Gwillimbury
N. and Gwillimbury E. twps
Kingsville R.P.D.— Gosfield N., Gosfield S.,
Mersea and Romney twps
Listowel R.P.D. — Elma, Grey, Marybor-
ough, Mornington, Peel, Wallace and
Wellesley twps
$ c.
36,380.21
*99,987.72
241,776.43
42,560.74
73,501.93
34,874.17
83,566.33
'140,126.10
'143,946.40
*60,641.77
79,885.82
103,742.88
71,710.60
145,534.40
181,689.73
'101,014.53
♦32,608.18
137,336.33
290,124.29
98,666.04
163,537.51
^288,182.64
117,836.37
$ c.
18,190.11
49,594.18
117,420.14
21,280.37
36,750.97
17,437.09
41,564.26
69,165.32
71,241.52
29,979.55
39,942.91
51,871.44
35,589.59
68,687.20
90,814.95
49,156.80
16,023.93
68,668.17
145,062.15
49,333.02
79,191.31
141,927.52
58.918.18
$ c
18,190.10
50,393.54
124,356.29
21,280.37
36,750.96
17,437.08
42,002.07
70,960.78
72,704.88
30,662.22
39,942.91
51,871.44
36,121.01
76,847.20
90,874.78
51,857.73
16,584.25
68,668.16
145,062.14
49,333.02
84,346.20
146,255.12
58,918.19
$ c.
1,551.97
3,541.93
14,587.39
1,262.66
4,608.40
2,759.11
3,533.11
6,278.56
11,694.02
1,589.70
6,130.70
4,212.87
4,173.17
17,652.41
12,129.72
8,444.96
863.57
13,190.41
11,877.49
7,836.82
18,268.52
19,670.19
4.818.83
Items marked * include portions of transmission lines aggregating $44,995.90 used for
1934
HYDRO-ELECTRIC POWER COMMISSION
187
RURAL POWER DISTRICTS N.— RURAL OPERATING
District, the revenues collected from (or charged to) customers within each District,
to the Municipalities comprising certain other Districts upon ascertainment
in the year ending October 31, 1933
Distribution costs and fixed charges
Total
cost
Revenue
from
power
and light
customers
Amounts remaining
Cost of
operation,
mainten
ance and
Interest
(including
exchange)
Renewal
charges
Obsoles-
cence
and
contin-
Sinking
fund
to be credited to
certain districts or
charged to the muni-
cipalities comprising
certain other
districts
adminis-
gencies
in each
district
tration
Credited
Charged
$ c.
$ c.
$ c.
$ c.
$ c.
$ c.
$ c.
$ c.
$ c.
793.41
838.42
723.32
361.66
190.42
4,459.20
4.212.04
247.16
3,857.09
2,323.56
1,988.61
994.30
527 71
13,233.20
12,123.59
1,109.61
10,174.62
5,653.01
4,738.26
2,369 13
1,283 87
38,806.28
39,122.90
316.62
2,126.71
915.84
790.12
395 06
208 00
5,698.39
3,382.96
2,315.43
3,680.20
1,691.53
1,459.32
729.66
384.17
12,553.28
10,433.94
2,119.34
2,363.03
800.42
690.54
345.27
181.78
7,140.15
5,359.88
1,780.27
4,996.24
1,912.29
1,641.02
820.51
434.30
13,337.47
10,335.89
3,001.58
5,081.21
3,268.51
2,783.91
2,724.32
1 391 96
742 32
19,546.47
28,201.83
22,491.59
27,338.72
2,945.12
8,504.68
3,191.76
1,362.16
724.89
863 . 1 1
1,751.08
1,405.12
1,198 63
599 31
319 12
6,862.96
14,169.82
13,594.05
9,862.87
36,067.55
6,739.23
123.73
3,481.10
1,807.88
1 559 70
779 85
410 59
13,596.51
12,080.99
8,195 23
573.31
3,400.20
2,372.28
2,046 62
1 023 31
538 77
1,513.06
1,885.20
1,515.33
1,296.68
2,785.40
648 34
344 15
1,667.64
10,043.04
3,417.79
1,392.70
776.21
36,066.39
1.16
6,724.29
4,107.57
3 542 49
1,771.25
993 90
932 88
29,208.20
21,541.05
3,781.42
26,153.23
37,554.77
18,725.70
34,488.48
50 080 96
26,339 07
2,869.13
7,210.17
2,366.71
1 987 80
537 51
17,608.63
2,779.18
29,043.50
33,272.88
18,161 72
3,932.42
1,012.55
762.38
646 51
323 26
173 15
1,002.24
5,037.57
3,143.45
2,711 .93
5,730.25
1 895 51
1,355.96
2,865.12
947 75
713 91
2,890.27
8,931.37
6,642.05
1,508.49
498 99
4,281.89
5.349.50
2,197.13
563.98
6,925.20
3,747.98
3,130.38
5,712.85
2,320.70
1,565.19
2,856.43
1,160.35
851 21
32,371.08
53,557.84
14,033.27
2,117.40
13,592.59
6,722.21
1 526 69
3,476.88
5,025.14
2,689.97
610.92
16,625.91
2,592.64
purposes of rural power districts.
188
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
NIAGARA SYSTEM—
Statement showing the costs of distribution of power within each Rural Power
and the amounts remaining to be credited to certain Districts or charged
(by annual adjustment) of the actual costs
District and municipalities
comprised therein
Total capital cost of each district,
Provincial Government grant re-
ceived and applied thereagainst,
and the balance representing the
investment by the Commission
Total
capital
cost
Govern-
ment
grant
Com-
mission's
investment
Cost of
power
delivered
to districts
as shown
in "cost of
power"
table
preceding
London R.P.D. — Delaware, Lobo, London,
Nissouri W. and Westminster twps
Lucan R.P.D.— Biddulph, London, McGil-
livray and Stephen twps
Lynden R.P.D. — Ancaster, Beverly, Brant-
ford and Dumfries S. twps
Markham R.P.D. — Markham, Pickering,
Scarborough, Uxbridge and Whitchurch
twps
Merlin R.P.D. — Raleigh, Romney and Til-
bury E. twps
Milton R.P.D. — Esquesing, Nassagaweya
Nelson and Trafalgar twps
Milverton R.P.D. — Ellice, Elma, Morning-
ton and Wellesley twps
Mitchell R.P.D.— Downie, Ellice, Elma,
Fullarton, Hibbert, Logan and McKillop
twps
Newmarket R.P.D. — Georgina, Gwillim-
bury E., King, Scott, Uxbridge and
Whitchurch twps
Niagara R.P.D. — Niagara and Stamford
twps
Norwich R.P.D. — Burford, Dereham
Middleton, Norwich N., Norwich S.
Oxford E. and Windham twps
Oil Springs R.P.D. — Brooke, Dawn, Ennis
killen and Euphemia twps
Palmerston R.P.D. — Arthur, Maryborough
Minto, Peel and Wallace twps
Petrolia R.P.D. — Enniskillen, Moore
Plympton and Sarnia twps
Preston R.P.D. — Dumfries N., Guelph
Puslinch, Waterloo and Woolwich twps.
Ridgetown R.P.D. — Aldborough, Harwich,
Howard, Orford and Rondeau Park twps.
St. Jacobs R.P.D.— Peel, Waterloo, Welles
ley and Woolwich twps
St. Marys R.P.D. — Blanshard, Downie
Fullarton, Nissouri E., Nissouri W. and
Usborne twps
St. Thomas R.P.D.— Dunwich, Southwold,
Westminster and Yarmouth twps
Saltfleet R.P.D.— Barton, Binbrook, Grims-
by N. and Saltfleet twps
Sandwich R.P.D. — Anderdon, Colchester
N., Maidstone, Sandwich E., Sandwich W.
and Sandwich S. twps
Sarnia R.P.D. — Moore, Plympton and
Sarnia twps
Scarboro R.P.D.— Pickering, Scarboro and
York N. twps
$ c.
♦452,460.60
♦58,020.83
103,260.55
♦228,562.66
143,247.28
108,488.53
65,164.42
109,781.46
120,385.47
♦126,194.33
♦181,308.61
29,686.23
♦60,312.85
♦26,075.59
♦318,742.34
202,560.06
107,601.88
192,453.85
304,957.81
$ c.
225,617.74
28,845.99
51,210.17
113,141.14
71,623.64
54,244.26
32,582.21
54,890.73
60,192.74
62,647.51
88,749.38
14,843.11
29,876.28
12,484.43
158,093.98
101,280.03
53,515.21
96,226.92
151,785.16
294,546.50 143,183.75
341,428.63
♦214,251.37
191,100.81
170,714.31
104,924.84
95,550.41
$
c.
226,842
86
29,174
84
52,050
38
115,421
52
71,623
64
54,244
27
32,582
21
54,890
73
60,192
73
63,546.82
92,559
23
14,843
12
30,436
.57
13,591
.16
160,648
.36
101,280.03
54,086.67
96,226.93
153,172
.65
151,362.75
170,714.32
109,326.53
95,550.40
$ c-
44,089.51
1,996.85
5,871.22
13,667.35
7,364.94
5,833.90
2,392.38
5,996.86
7,898.87
9,080.52
8,427.21
1,772.69
2,021.78
972.89
25,945.67
10,980.99
7,887.08
7,568.26
14,249.36
28,553.81
27,719.20
18,548.93
10,007.34
Items marked * include portions of transmission lines aggregating $44,995.90 used for
1934
HYDRO-ELECTRIC POWER COMMISSION
89
RURAL POWER DISTRICTS N — RURAL OPERATING
District, the revenues collected from (or charged to) customers within each District,
to the Municipalities comprising certain other Districts upon ascertainment
in the year ending October 31, 1933
Distribution costs and
fixed charges
Total
cost
Revenue
from
power
and light
customers
in each
district
Amounts remaining
Cost of
operation
mainten-
ance and
adminis-
Interest
(including
exchange)
Renewal
charges
Obsoles-
cence
and
contin-
gencies
Sinking
fund
to be credited to
certain districts or
charged to the muni-
cipalities comprising
certain other
districts
tration
Credited
Charged
$ c.
$ c.
$ c.
$ c.
$ c.
$ c.
$ c.j $ c.
$ c.
23,894.84
10,359.88
8.913.20
4,456.60
2,352.85
94,066.88
93,203.47
863.41
1,192.16
1,350.75
1,158.74
579.38
306.77
6,584.65
6,542.13
42.52
4,536.55
2,357.16
2,022.91
1,011.45
535.34
16,334.63
14,031.73
2,302.90
7,552.03
5,225.01
4,462.13
2,231.04
1,186.66
34,324.22
39,491.40
5,167.18
3,425.68
3,267.36
2,818.83
1,409.41
742.06
19,028.28
17,837.26
1,191.02
4,223.46
2,469.70
2,130.67
1,065.34
560.90
16,283.97
15,225.32
1,058.65
2,409.50
1,482.21
1,278.74
639.37
336.63
8,538.83
7,201.22
1,337.61
3,748.52
2,440.38
2,105.37
1,052.69
554.24
15,898.06
16,195.71
297.65
3,914.38
2,671.93
2,305.13
1,152.57
606.83
18,549.71
19,344.75
795.04
9,532.58
2,912.12
2,494.37
1,247.18
661.39
25,928.16
23,248.04
2,680.12
8,472.34
4,249.76
3,590.22
1,795.11
965 . 17
27,499.81
25,308.22
2,191.59
1,800.59
685.06
591.02
295.51
155.59
5,300 46
5,288.04
12.42
1,694.95
1,401.93
1,198.27
599.13
318.39
7,234.45
4,930.36
2,304.09
1,163.87
620.76
7,166.19
513.41
6,131.35
256.71
3,065.67
140.98
1,627.53
3,668.62
55,102.21
3,599.06
53,998.49
69.56
11,165.80
1,103.72
7,479.68
4,648.66
4,010.50
2,005.25
1,055.77
30,180.85
29,529.41
651.44
6,101.84
2,472.39
2,121.. 55
1,060.78
561.51
20,205.15
17,133.19
3,071.96
5,428.34
4,408.81
3,803.58
1,901.79
1,001.29
24,112.07
20,841.54
3,270.53
12,358.85
6,913.74
5,936.89
2,968.44
1,570.19
43,997.47
46,282.43
2,284.96
17,636.31
6,882.96
7,851.31
5,774.50
6,773.50
2,887.25
3,386.75
1,563.20
1,783.12
63,298.03
70,672.66
65,998.50
69,667.54
2,700.47
23,158.78
1,005.12
13,453.68
4,959.12
4,190.30
2,095.16
1,126.27
44,373.46
47,313.52
2,940.06
5,993.13
4,202.75
3,625.81
1,812.90
954.49
26,596.42
33,354.35
6,757.93
purposes of rural power districts.
190
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
NIAGARA SYSTEM—
Statement showing the costs of distribution of power within each Rural Power
and the amounts remaining to be credited to certain Districts or charged
(by annual adjustment) of the actual costs
District and municipalities
comprised therein
Total capital cost of each district,
Provincial Government grant re-
ceived and applied thereagainst,
and the balance representing the
investment by the Commission
Total
capital
cost
Govern-
ment
grant
Com-
mission's
investment
Cost of
power
delivered
to districts
as shown
in "cost of
power"
table
preceding
Seaforth R.P.D.— Hibbert, Hullett, McKil-
lop and Tuckersmith twps
Simcoe R.P.D. — Charlotteville, Townsend,
Walpole, Windham and Woodhouse twps.
Stamford R. P. D.— Stamford and Thorold
twps
Stratford R.P.D.— Downie, Easthope N.,
Easthope S. and Ellice twps
Strathroy R.P.D.— Adelaide, Caradoc, Ek-
frid, Lobo, Metcalfe and Williams E.
twps
Streetsville R.P.D. — Chinguacousy, Esque-
sing, Toronto and Trafalgar twps
Tavistock R.P.D. — Easthope N., Easthope
S., Ellice and Zorra E. twps
Thamesville R.P.D. — Camden, Chatham,
Euphemia, Harwich, Howard, Orford and
Zone twps
Tilbury R.P.D.— Dover W., Mersea, Roch-
ester, Romney, Tilbury E., Tilbury W.
and Tilbury N. twps
Tillsonburg R.P.D. — Bayham, Dereham,
Dorchester S., Houghton, Malahide, Mid-
dleton, Norwich N., Norwich S. and Wal-
singham N. twps
Wallaceburg R.P.D.— Chatham, Dover E.
and Sombra twps
Walsingham R.P.D. — Charlotteville,
Houghton, Middleton, Walsingham N.,
Walsingham S. and Windham twps
Walton R.P.D.— Grey, Hullett, McKillop,
Morris, Wawanosh E. and Wawanosh W.
twps
Waterdown R.P.D. — Flamboro E., Flam-
boro W. and Nelson twps
Waterford R.P.D. — Townsend and Wind-
ham twps
Watford R.P.D.— Adelaide, Metcalfe and
Warwick twps
Welland R.P.D.— Bertie, Crowland, Hum-
berstone, Moulton, Pelham, Thorold, Wain-
fleet and Willoughby twps
Woodbridge RP.D. — Albion, Chinguacousy,
Etobicoke, King, Toronto, Toronto Gore,
Vaughan and York N. twps
Woodstock R.P.D.— Blandford, Blenheim,
Burford, Oxford E., Oxford N., Oxford W..
Zorra E. and Zorra W. twps
Non-operating capital
Grand totals
Items marked * include portions of
$ c.
29,402.80
129,831.68
41,211.74
67,079.92
101,204.09
187,700.07
120,629.22
107,547.60
♦110,648.45
201,568.67
154,326.32
*148,749.14
*80,210.08
205,749.58
117,271.01
23,904.03
*652,765.71
*338,237.05
224,924.58
$ c.
14,083.46
64,745.55
20,605.87
33,279.11
50,425.27
93,850.04
60,314.61
53,522.31
54,700.13
100,784.33
76,792.14
73,865.05
38,349.04
92,521.64
58,635.51
11,952.02
321,346.74
168,240.65
112,462.29
12,823,206.79
15,149.60
6,345,677.89
7,371.69
12,838,356 39 6,353,049. 58 6,485,306. 81 810,110 . 29
$ c.
15,319.34
65,086.13
20,605.87
33,800.81
50,778.82
93,850.03
60,314.61
54,025.29
55,948.32
100,784.34
77,534.18
74,884.09
41,861.04
113,227.94
58,635.50
11,952.01
331,418.97
169,996.40
112,462.29
$ c.
1,942.11
6,876.76
4,071.99
4,598.14
3,658.40
10,675.09
5,087.05
3,563.14
6,039.71
10,433.41
7,002.40
6,623.11
4,132.10
21,894.57
4,962.07
985.51
30,967.62
17,636.20
14,704.05
6,477,528.90
7,777.91
transmission lines aggregating $44,995.90 used for
1934
HYDRO-ELECTRIC POWER COMMISSION
191
RURAL POWER DISTRICTS N.— RURAL OPERATING
District, the revenues collected from (or charged to) customers within each District,
to the Municipalities comprising certain other Districts upon ascertainment
in the year ending October 31, 1933
Distribution costs and fixed charges
Cost of
operation
mainten-
ance and
adminis-
tration
Interest
(including
exchange)
Renewal
charges
Obsoles-
cence
and
contin-
gencies
Sinking
fund
Total
cost
Revenue
from
power
and light
customers
in each
district
1,484.93
4,835 . 74
4,659.19
4,672.33
2,611.26
6,690.41
5,557.04
3,910.29
3,159.47
8,080.12
6,290.43
4,136.83
3,688.75
13,589.85
4,002.21
572.40
28,211.50
13,591.40
10,233.83
$ c.
708.06
2,993.53
945.43
1,547.12
2,328.00
4,280.02
2,782.08
2,494.36 2,141
$ c.
586.15
2,575.77
815.64
1,324.30
2,001.35
3,692.47
2,400.16
2,548.13
4,633.17
3,902.45
3,282.55
2,173.36
3,997.14
3,352.32
2,811.55
$ c.
293.07
1,287.89
407.82
662.16
1,000.68
1,846.23
1,200.08
1,070.94
1,086.68
1,902.07 1,570.71
5,068.67
2,672.46
554.08
14,680.64
7,732.95
5,164.94
3,958.73
2,305.59
478.02
12,466.75
6,636.72
4,455 91
$
160.81
679.87
214.72
351.37
528.71
972.04
631.84
566.50
578.71
1,998.57 1,052.25
886.29
1,676.16
1,405.78
785.35
1,979.36
1,152.80
239.01
6,233.38
3,318.36
2,227.95
745.50
431.98
1,151.15
606.95
125.84
3,334.13
1,756.25
1,173.02
$ c
5,175.13
19,249.56
11,114.79
13,155.42
12,128.40
28,156.26
17,658.25
13,747.11
15,586.06
30,194.66
23,110.05
19,005.32
12,510.96
47,642.33
15,702.08
2,954.86
95,894.02
50,671.88
37,959.70
$ c.
4,988.00
18,401.72
11,625.74
11,861.74
11,961.96
25,199.26
15,057.50
13,177.66
16,141.44
27,772.02
21,911.32
20,529.21
11,960 01
49,697.37
15,682.41
3,051.33
92,375.20
50,554.59
35,997.86
Amounts remaining
to be credited to
certain districts or
charged to the muni-
cipalities comprising
certain other
districts
Credited Charged
510.95
$ c.
187.13
847.84
555.38
1,293.68
166 44
2,957.00
2,600.75
569.45
1,523.89
2,055.04
96.47
2,422.64
1,198.73
550.95
19.67
3,518.82
117.29
1,961.84
557,105.44 294,442.54 251.397.57 125,698.79 66,871.35
2,105.625 9812,063,370.73
50.246.15
92,501.40
purposes of rural power districts.
92
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
NIAGARA
Statement showing the net Credit or Charge to each Municipality in respect of power
made and interest added during the year. Also the net amount Credited
ending October 31, 1933, and the accumulated amount standing
Municipality
Date
commenced
operating
Net credit or charge at
October 31, 1932
Credit
Charge
Cash receipts and
payments on account
of such credits and
charges, also adjust-
ments made during
the year
Credited I Charged
Acton
Agincourt. . . .
Ailsa Craig. . .
Alvinston ....
Amherstburg .
Ancaster twp.
Arkona
Aylmer
Ayr
Baden
Beachville. . . .
Belle River. . .
Blenheim
Blyth
Bolton
Bothwell
Brampton. . . .
Brantford. . . .
Brantford twp
Bridgeport . . .
Brigden
Brussels
Burford
Burgessville. .
Caledonia. . . .
Campbellville.
Cayuga
Chatham ....
Chippawa. . . .
Clifford
Clinton
Comber
Cottam
Courtright . . .
Dashwood. . . .
Delaware ....
Dorchester. . .
Drayton
Dresden
Drumbo
Dublin
Dundas
Dunnville. . . .
Dutton
East Windsor
Jan.,
1913
Nov., ]
1922
Jan.,
916
April, 1
[922
Nov., 1
[925
May, 1
923
Dec, 1
926
Mar., 1
918
Jan.,
915
May, 1
[912
Aug., 1
[912
Dec, 1
[922
Nov., 1
L915
July, 1
[924
Feb., ]
[915
Sept., 1
915
Nov., 1
911
Feb., 1
[914
May, 1
924
Mar., 1
928
Jan.,
918
July, 1
924
June, 1
915
Nov., 1
916
Oct., ]
[912
Jan., 1
[925
Nov., 1
924
Feb., ]
[915
Sept., 1
919
May, 1
[924
Mar., 1
[914
May,
1915
Nov., 1
L926
Dec, 1
L923
Sept.,
L917
Mar.,
1915
Dec,
1914
Mar.,
1918
April,
1915
Dec,
1914
Oct.,
1917
Jan.,
1911
June,
L918
Sept.,
1915
Nov.,
1922
289.61
532.55
4,595.75
23.18
1,499.70
860.59
515.07
1,325.66
305.29
642.78
655.94
4,145.83
470.48
772.85
833.61
315.96
234.05
144.41
725.22
7,288.41
512.92
181.36
577.54
597.54
194.97
99.94
297.46
73.87
652.84
479.05
1,497.51
3,181.73
1,157.11
4,731.69
$ c
9.50
24.83
29.59
276.51
627.60
5,618.58
286.06
688.85
4.43
65.98
287.01
$ c
9.50
24.83
32.26
276.51
627.60
5,618.58
286.06
688.85
0.39
4.43
65.98
289.61
532.55
4,595.75
2.67
23.18
1,499.70
860.59
515.07
1,325.66
305.29
642.78
655.94
4,145.83
470.48
772.85
833.61
315.96
234.05
144.41
725.22
7,288.41
512.92
181.36
577.54
597.54
194.97
99.94
297.46
74.26
652.84
479.05
1,497.51
3,181.73
1,157.11
4,731.69
1934
HYDRO-ELECTRIC POWER COMMISSION
193
SYSTEM
N. —CREDIT OR CHARGE
supplied to it to October 31, 1932, the cash receipts and payments thereon, adjustments
or Charged to each Municipality in respect of power supplied in the year
as a Credit or Charge to each Municipality at October 31, 1933
Interest at 4 % per annum
added during the year
Net amount credited or charged
in respect of power supplied in
the year endingOctober31, 1933
Accumulated amount standing
as a credit or charge on
October 31, 1933
Credited
Charged
Credited
Charged
Credit
Charge
$ c.
$ c.
0.12
$ c.
$ c.
13.01
$ c.
$ c.
13.13
4.00
232.09
236.09
9.39
210.04
200.65
0.33
330.14
1,754.23
329.81
1,826.33
72.10
0.44
357.51
14.36
6.17
357 95
.38
13 98
19.56
13.39
60.09
15.35
44.74
7.06
168.86
161 80
18.46
452.58
471.04
5.05
162.79
157 74
4.33
259.78
392.91
529.66
255.45
402.98
539.36
10.07
9.70
9.35 .
137.89
1,892.62
4,467.37
733.10
27.04
147 24
53.16
1,839.46
4,475.92
737 99
8.55
4.89
6.24
20 80
10.25
355.18
396.07
189.59
365.43
408 . 95
194.68
12.88
5.09
11.77
208 . 45
659.56
35.12
432.41
523.64
41.83
372.01
495 . 93
220 22
3.16
656 40
1.98
33 14
10.74
421 67
100.64
423 00
9.82
32 01
2.88
369. 13
7.78
488 15
7.55
278.70
70.64
286.25
73.70
3.06
1.65
253.32
89.19
251 67
4.09
85 10
1.37
"o.'io"
0.82
4.50
5.87
234.30
379.08
234 40
379 90
9.23
338.43
258.80
347.66
267.07
8.27
11.48
109.99
1,520.21
408 48
24.29
1,495.92
44.84
3,475.50
340.39
3,520.34
354.72
14.33
70.00
1,082.44
1,012.44
194
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
NIAGARA
Statement showing the net Credit or Charge to each Municipality in respect of power
made and interest added during the year. Also the net amount Credited
ending October 31, 1933, and the accumulated amount standing
Municipality
Date
commenced
operating
Net credit or charge at
October 31, 1932
Credit Charge
Cash receipts and
payments on account
of such credits and
charges, also adjust-
ments made during
the year
Credited | Charged
Elmira
Elora
Embro
Erieau
Erie Beach
Essex
Etobicoke
Exeter
Fergus
Fonthill
Forest
Gait
Georgetown
Glencoe
Goderich
Granton
Guelph
Hagersville
Hamilton
Harriston
Harrow
Hensall
Hespeler
Highgate
Humberstone
Ingersoll
Jarvis
Kingsville
Kitchener
Lambeth
La Salle
Leamington
Listowel
London
London Railway Commission . .
London twp
Long Branch
Lucan
Lynden
Markham
Merlin
Merritton
Milton
Milverton
Mimico
Nov.,
1913
Nov.,
1914
Jan.,
1915
July,
1924
July,
1925
Nov.,
1923
Aug.,
1917
June,
1916
Nov.,
1914
June,
1926
Mar.,
1917
May,
1911
Sept.,
1913
Aug.,
1920
Feb.,
1914
July,
1916
Dec,
1910
Sept.,
1913
Feb.,
1911
July,
1916
Nov.,
1923
Jan.,
1917
Feb.,
1911
Dec,
1916
Oct.,
1924
May,
1911
Feb.,
1924
Nov.,
1923
Jan.,
1911
April,
1915
Nov.,
1925
Nov.,
1923
June,
1916
Jan.,
1911
Aug.,
1914
Jan.,
1925
Jan.,
1931
Feb.,
1915
Nov.,
1915
April,
1920
Dec,
1922
Nov.,
1920
April,
1913
June,
1916
May,
1912
$ c.
524.45
785.20
842.66
50.72
236.36
6,103.00
1,357.60
78.79
429.11
14,435.61
1,677.99
2,003.92
539.63
3,828.92
471.50
1,547.18
1,989.97
453.45
311.39
3,985.55
899.87
52,818.01
,096.56
191.94
348.30
1,063.88
791.61
1.043.59
5.40
5.40
129.94
129.94
305.46
540.12
511.15
68.59
4,455.14
305.46
545 66
511.15
68.59
4,455.14
122,122.18
625.15
122,122.18
625 15
134.68
534.54
2,521.53
134.68
534.54
2,521.53
12.298.53
12,298.53
356.08
356.08
51.18
662.61
51 18
662.61
10.98
10.98
$ c
524.45
785 . 20
842.66
50.72
236.36
6,103.00
1,357.60
78.79
429.11
14,435.61
5.54
1,677.99
2,003.92
539.63
3,828.92
471.50
1,547.18
1,989.97
453.45
311.39
3,985.55
899 87
52,818.01
1,096.56
191.94
348.30
1,063.88
791.61
1,043 '59
1934
HYDRO-ELECTRIC POWER COMMISSION
195
SYSTEM
N.— CREDITOR CHARGE
supplied to it to October 31, 1932, the cash receipts and payments thereon, adjustments
or Charged to each Municipality in respect of power supplied in the year
as a Credit or Charge to each Municipality at October 31, 1933
Interest at 4
added dur
% per annum
ing the year
Net amount credited or charged
in respect of power supplied in
the year ending October 31, 1933
Accumulated amount standing
as a credit or charge on
October 31, 1933
Credited
Charged
Credited Charged
Credit Charge
$ c.
7.18
$ c.
$ c.
$ c.
540.61
516.81
$ c.
$ c.
533 . 43
9.98
506.83
11.67
350.58
263.69
77.41
362.25
263.59
78.13
0.10
0.72
3.91
35.06
" 198 '. 65 "
886.23
31.15
82.27
2,781.24
2,863.51
19.29
179.36
1.13
885 10
2.32
321.55
870.45
424.70
319.23
876.05
624.46
"280.*53"
5.60
199.76
4.28
10.09
6.89
1.26 .
82.02
807.68
811.96
290.62
1,427.19
210.56
2,622.42
1,989.73
80,489.92
607.37
1,434.08
211 82
2,704.44
1,960 06
29.67
2,127.94
12.07
82,617.86
619 44
30.69
102.52
133.21
10.31
172.04
161 73
61.76
2,850.17
134.79
2,911.93
132.78
2.01
6.95
43.34
162.12
3,712.82
995.86
169.07
3,756.16
988 06
7.80
22.50
70.34
92.84
26.39
5,493.50
5,467.11
8.84
152.94
104.24
161.78
108.47
4.23
62.46
393.56
704.11
7,509.92
8,333.61
331 10
13.81
690 30
711.96
6,797.96
8,647.14
313.53
14.06
278.35
618.14
292.41
613.34
4.80
2.44
85.69
S3 25
7.53
147.75
543.53
155.28
558. £8
15.35
0.72
8.53
103.28
719.66
1,119.83
251.62
195.89
104 00
728 19
9.98
1,109.85
251 76
0.14
17.27
178 62
196
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
NIAGARA
Statement showing the net Credit or Charge to each Municipality in respect of power
made and interest added during the year. Also the net amount Credited
ending October 31, 1933, and the accumulated amount standing
Municipality
Date
commenced
operating
Net credit or charge at
October 31, 1932
Credit
Charge
Cash receipts and
payments on account
of such credits and
charges, also adjust-
ments made during
the year
Credited | Charged
Mitchell
Moorefield
Mount Brydges. . . .
Newbury
New Hamburg
New Toronto
Niagara Falls
Niagara-on-t he-Lake
Norwich
Oil Springs
Otterville
Palmerston
Paris
Parkhill
Petrolia
Plattsville
Point Edward
Port Colborne
Port Credit
Port Dalhousie
Port Dover
Port Rowan
Port Stanley
Preston
Princeton
Queenston
Richmond Hill
Ridgetown
Riverside
Rockwood
Rodney
St. Catharines
St. Clair Beach
St. George
St. Jacobs
St. Marys
St. Thomas
Sandwich
Sarnia
Scarboro twp
Seaforth
Simcoe
Springfield
Stamford twp
Stouffville
Sept.,
1911
Mar.,
918
Mar.,
L915
Mar.,
L921
Mar., 1
1911
Feb., 1
L914
Dec, 1
[915
Aug., 1
L919
May, 1
L912
Feb., 1
L918
Feb., 1
1916
July, 1
[916
Feb., 1
[914
May, 1
1920
May, 1
1916
Dec, 1
1914
Nov., 1
[916
Mar., 1
[920
Aug., 1
L912
Nov., ]
912
Dec, 1
[921
Nov., 1
[926
April, 1
L912
Jan., ]
L911
Jan., ]
[915
Mar., 1
[921
June, 1
[925
Dec, 1
L915
Nov., 1
[922
Sept.,
[913
Feb., 1
L917
April,
L914
Nov.,
L922
Sept.,
L915
Sept.,
[917
May,
[911
April, 1
[911
Feb.,
924
Dec,
L916
Aug.,
1918
Nov.,
1911
Aug.,
1915
Aug.,
1917
Nov.,
916
Sept.,
1923
$ c
1,057.54
33.40
550.78
552.05
6,749.02
68.61
428.82
2,215.41
691.96
1,359.79
825.29
2,738.99
214.50
274.20
806 . 94
.642.85
1,009.94
105.39
1,739.77
3,201.68
529.93
252.82
29.42
298.36
2,632.30
15,827.24
5,511.51
23,767.17
5,133.02
285.33
2,954.96
983.06
$ c,
149.22
30,619.69
216.74
381.81
275.75
199.38
247.95
222.22
419.58
435.48
12,934.36
121.83
609.18
$ c
149.22
336.37
216.74
381.81
275.75
199.38
247.95
222.22
419.58
435 . 48
12,934.36
121.83
609.18
$ c
1,057.54
33.40
550.78
552.05
6,749.02
68.61
428.82
2,215.41
691.96
1,359.79
825.29
2,738.99
214.50
274.20
806.94
1,642.85
1,009.94
105.39
1,739.77
3,201.68
529.93
252.82
29.42
298.36
2,632.30
15,827.24
5,511.51
23,767.17
5,133.02
285.33
2,954.96
983.06
934
HYDRO-ELECTRIC POWER COMMISSION
97
SYSTEM
N.— CREDIT OR CHARGE
supplied to it to October 31, 1932, the cash receipts and payments thereon, adjustments
or Charged to each Municipality in respect of power supplied in the year
as a Credit or Charge to each Municipality at October 31, 1933
Interest at 4 % per annum
added during the year
Net amount credited or charged
in respect of power supplied in
the year ending October 31, 1933
Accumulated amount standing
as a credit or charge on
October 31, 1933
Credited
Charged
Credited Charged
Credit
Charge
$ c.
16.21
$ c.
$ c.
$ c.
195.84
171.93
$ c.
$ c.
179.63
0.49
1 7 1 . 44
7.90
108.39
50.54
439.93
5,841.19
116.29
48.58
447.67
5,935.12
1.96
7.74
93.93
1,211.33
18,404.74
66.80
220.71
49,899.39
0.93
65.87
2.92
223 . 63
5.92
578.83
584.75
4.90
4.38
168.27
330.31
540.79
173.17
334 . 69
31.56
509.23
11.25
87.07
2,325.04
258.40
1,626.75
1,258.41
98.32
2,343.97
271.58
1,666.03
1,255.29
18.93
13.18
39.28
3.12
3.48
827.89
189.87
831.37
2.84
187.03
3.85
1,275.30
294.00
1,020.46
1,279.15
302.22
1,057.22
8.22
36.76
2.95
1,221.18
1,224.13
15.83
520.82
89.20
1,719.01
41.96
536.65
90.68
1,755.00
35.71
1.48
35.99
6.25
47.37
732.20
684 83
7.64
103.47
111.11
6.49
229.86
388.35
5,056.45
109.04
394 84
5,286.31
105 30
3.74
0.37
215.67 .
216.01
3.76
396.03
2,099.66
392 27
42.69
2,056.97
230.05
1,591.19
973.99
10,873.22
4,066.22
1,821.24
1,050.70
11,211.35
4,134.29
76.71
338.13
68.07
3.81
316.44
312 63
42.10
2,195.33
2,237.43
1.70
9.35
63.79
1,475.80
65 49
1,485.15
19.80
248.99
268.79
198
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
NIAGARA
Statement showing the net Credit or Charge to each Municipality in respect of power
made and interest added during the year. Also the net amount Credited
ending October 31, 1933, and the accumulated amount standing
Municipality
Date
commenced
operating
Net credit or charge at
October 31, 1932
Credit
Charge
Cash receipts and
payments on account
of such credits and
charges, also adjust-
ments made during
the year
Credited | Charged
Stratford
Jan.,
Dec,
Aug.,
Nov.,
Nov.,
Feb.,
Oct.,
May,
Mar.,
Jan.,
April,
Aug.,
June,
Aug.,
Nov.,
Feb.,
June,
Nov.,
April,
Dec,
Sept.,
Sept.,
Nov.,
Jan.,
Jan.,
Feb.,
Oct.,
Dec,
Jan.,
Nov.,
July,
Nov.,
Sept.
Jan.,
Feb.,
Sept.
June,
Nov.
Nov.
1911
1914
1923
1916
1922
1914
1915
1922
1914
1921
1915
1911
1911
1913
1914
1915
1921
1911
1915
1910
1917
1917
1916
1917
1911
1924
1914
1914
1911
1916
1925
1923
1917
1927
1928
1930
1929
1923
1922
$ c
25,236.86
3,540.38
1,281.56
$ c
$ c
$ c
25,236.86
Strathroy
3,540.38
Sutton
1,281.56
Tavistock
512.16
512.16
Tecumseh
1,285.29
451.58
1,285.29
Thamesford
451.58
Thamesville
188.03
188.03
Thedford
54.12
164.69
705.82
1,833.67
1,151.98
69,566.26
1,723.27
9,900.02
750.53
54.12
Thorndale
5.56
170.25
Thorold
705.82
Tilbury
1,833.67
Tillsonburg . .
1,151.98
Toronto
69,566.26
Toronto twp...
1,723.27
Walkerville
9,900.02
Wallaceburg
750.53
Wardsville . .
147.77
147.77
326.83
Waterdown
674.64
650.51
3,855.37
644.19
1,001.47
Waterford
650.51
Waterloo
3,855.37
Watford
644.19
Wei land
4,105.12
218.78
4,140.87
218.78
35.75
Wellesley . .
West Lome. .
49.56
3,705.30
695.94
39,254.28
292.01
5,128.64
49.56
Weston . . .
3,705.30
Wheat ley
695.94
39,254.28
Woodbridge
292.01
Woodstock
5,128.64
Wyoming
352.34
352.34
York East twp.
3,310.59
3,310.59
York North twp.
761.30
761.30
Zurich
542.00
1,820.35
542.00
Toronto Transportation Comm .
Rural Power District*
Acton R.P.D.
1,820.35
416.70
30.00
Ailsa Craig R.P.D
Alvinston R P D
42.22
413.45
Amherstburg R.P.D
Aylmer R.P.D
27,651.27
13,222.77
148.56
883.51
*For townships included in rural power districts see "Cost of Power" and "Rural Operating'
statements preceding.
934
HYDRO-ELECTRIC POWER COMMISSION
199
SYSTEM
N.— CREDIT OR CHARGE
supplied to it to October 31, 1932, the cash receipts and payments thereon, adjustments
or Charged to each Municipality in respect of power supplied in the year
as a Credit or Charge to each Municipality at October 31, 1933
Interest at 4 % per annum
added during the year
Net amount credited or charged
in respect of power supplied in
the year ending October 31, 1933
Accumulated amount standing
as a credit or charge on
October 31, 1933
Credited
Charged
Credited Charged
Credit Charge
% c.
376.71
$ c.
$ c.
2,756.37
2,132.17
504.99
665.99
$ c.
$ c.
3,133.08
2,187.65
524.95
658.13
$ c.
55.48
19 96
7.86
19.01
128.49
76.01
109.48
6.28
69 . 73
3.71
357.95
497.13
57.04
38.36
354.24
498.03
59.66
47.87
0.90
2.62
9.51
27.61
164.20
136.59
15.15
30.73
45.88
937.71
118,851.10
117,913.39
24.17
1,472.78
1,496.95
146.47
4,981.98
711.90
4,835.51
701 54
10.36
3.77
43.17
126.04
486.71
39.40
137.64
494.84
11.60
8.13
48.17
14,197.04
14,148.87
10.66
1,037.11
1,047.77
112.06
2.90
572.39
684.45
49.34
50.81
1,642.37
46.44
51.54
1,698.00
0.73
55.63
10.16
219.96
8,015.38
209 80
546.33
7,469.05
3.90
475.00
478.90
82.62
4,667.50
4,584.88
5.33
269.47
2,353.09
1,244.66
264.14
2,396.63
1,229.81
43.54
14.85
7.66
127.04
119 38
29.99
359.71
389.70
16.67
251.34
74.49
196.43
714 71
1.69
30.58
16.54
626 42
1,105.82
3,157.82
1,594.09
31,766.35
14,460.63
527.28
200
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
NIAGARA
Statement showing the net Credit or Charge to each Municipality in respect of power
made and interest added during the year. Also the net amount Credited
ending October 31, 1933, and the accumulated amount standing
Rural power
district*
Date
commenced
operating
Net credit or charge at
October 31, 1932
Cash receipts and
payments on account
of such credits and
charges, also adjust-
ments made during
the vear
Credit Charge
Credited ( Charged
Ayr R.P.D
Baden R.P.D
Beamsville R.P.D..
Belle River R.P.D.
Blenheim R.P.D..
Bond Lake R.P.D..
Bothwell R.P.D.. .
Brampton R.P.D..
Brant R.P.D
Brigden R.P.D.. . .
Burford R.P.D. ...
Caledonia R.P.D..
Chatham R.P.D.. .
Chippawa R.P.D..
Clinton R.P.D. . .
Delaware R.P.D. .
Dorchester R.P.D.
Dresden R.P.D
Drumbo R.P.D
Dundas R.P.D
Dunnville R.P.D..
Dutton R.P.D
Elmira R.P.D
Elora R.P.D
Essex R.P.D
Exeter R.P.D
Forest R.P.D
Gait R.P.D
Georgetown R.P.D
Goderich R.P.D. .
Grantham R.P.D.
Guelph R.P.D
Haldimand R.P.D.
Harriston R.P.D.. .
Harrow R.P.D
Ingersoll R.P.D.. . .
Jordan R.P.D
Keswick R.P.D
Kingsville R.P.D.. .
Listowel R.P.D
London R.P.D
Lucan R.P.D
July,
1926
Sept.,
1922
Jan.,
1923
Dec,
1922
July,
1924
Mar.,
1924
Dec,
1923
Nov.,
1923
Oct.,
1922
Jan.,
1927
Dec,
1926
Oct.,
1925
May,
1922
July,
1922
July,
1928
Oct.,
1922
Dec,
1921
May,
1928
Aug.,
1922
Jan.,
1922
July,
1928
Feb.,
1926
June,
1926
Jan.,
1926
Nov.,
1924
Nov.,
1922
Nov.,
1926
Oct.,
1922
Nov.,
1924
June,
1925
Nov.,
1924
Jan.,
1925
Oct.,
1925
Dec,
1929
Nov.,
1923
Oct.
1922
May,
1922
Mar.,
1924
Nov.,
1923
Oct.,
1926
Nov.,
1922
June,
1926
$ c
929.50
42,906.65
31,123.02
15,790.10
48,163.85
6,868.19
919.69
2,612.52
17,757.86
3,331.26
3.602.59
1,190.94
19,959.94
17,870.19
12,726.42
2,729.5
2,485.24
1,083.72
' 4,132.77
16,262.32
12,619.14
34,612.32
587.85
17,784.51
$ c. $ c
2,618.01
3,050.86
3,264.22
2,611.19
1.921.11
1,861.59
305.41
2,725.54
693.35
1,580.47
629.88
235.14
1,942.70
7,324.28
1,241. Oi
2,192.54
6,781 .22
298.13
88.15
187
HI
814
15
177
07
30
00
932
99
172
94
117
69
1,590
00
20
00
300
00
1,287
82
60
71
150
00
240
00
656
52
417
98
429.27
596.55
30.00
122.00
204.08
20.00
3.50
372.59
40.00
674.21
174.36
726.86
20.00
120.00
113.50
174.01
334.97
320.00
144.76
V
174.10
*For townships included in rural power districts see '"Cost of Power" and "Rural Operating'
statements preced-ng.
1934
HYDRO-ELECTRIC POWER COMMISSION
201
SYSTEM
N.— CREDIT OR CHARGE
supplied to it to October 31, 1932, the cash receipts and payments thereon, adjustments
or Charged to each Municipality in respect of power supplied in the year
as a Credit or Charge to each Municipality at October 31, 1933
Interest at 4 % per annum
added during the year
Net amount credited or charged
in respect of power supplied in
the year ending October 31, 1933
Accumulated amount standing
as a credit or charge on
October 31, 1933
Credited
Charged
Credited
Charged
Credit
Charge
$ c.
37 18
$ c.
$ c.
$ c.
1,275.26
3,320.11
$ c.
$ c.
308.58
104.72
6,230 65
1,715.08
1,244.54
631.60
1,110.55
1,585.93
2,395.57
4,665.38
44,918.13
33,776.42
18,787.27
53,817.20
6,459.85
1,920.96
274 73
'
510.13
1,461.14
5,214.29
1,192.55
379.20
2,685.01
148.48
25.89
1,271.81
251.28
36 38
622.76
122.03
130.57
9,977.18
4,607.34
104 50
2,037.82
111.72
6,695.74
709.92
18,258.59
3,288.62
133.25
76.84
3,509.76
139 65
2,834.44
76.61
12.22
422.90
1,933.28
247.16
1,109.61
564.79
47.64
128.97
20,644.73
797.44
316.62
109.02
37.01
63.22
25.39
2,315.43
2,119.34
1,780.27
3,001.58
5,149.99
3,446.25
3,453.96
3,778.85
714 69
2,945.12
21,325.92
12,352.37
509.06
863.11
123.73
573.31
1,513.06
1,667.64
1.16
2,869.13
3,932.42
1,002.24
9.41
368.28
109.18
2,261.88
698.86
99.27
77.71
3,728.05
42.91
451.26
292.97
10,659.74
165.31
361.20
49.64
2,312.89
650 . 49
2,890 27
19,683.08
87.93
4,281.89
563.98
2,117.40
6,676 86
504 14
12,385.29
273.72
9,507.31
1,384.79
23.43
3,476.88
39,242.14
2,592.64
863.41
42.52
2,126.12
710.43
17,457.43
11.93
352.58
202
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
NIAGARA
Statement showing the net Credit or Charge to each Municipality in respect of power
made and interest added during the year. Also the net amount Credited
ending October 31, 1933, and the accumulated amount standing
Rural power district*
Date
commenced
operating
Net credit or charge at
October 31, 1932
Cash receipts and
payments on account
of such credits and
charges, also adjust-
ments made during
the year
Credit |
Charge
Credited | Charged
Lvnden R.P.D
Feb.,
Dec,
Nov.,
Jan.,
Aug.,
Dec,
Mar.,
Jan.,
May,
Dec,
Oct.,
Aug.,
April,
Mar.,
Nov.,
Dec,
Aug.,
Feb.,
July,
June,
Dec,
Nov.,
Nov.,
Mar.,
July,
Dec,
Nov.,
April,
Nov.,
Dec,
Dec,
Jan.,
Dec,
Nov.,
Oct.,
Nov.,
Dec,
April
Jan.,
Feb.,
1922
1922
1928
1925
1927
1925
1924
1922
1925
1925
1926
1923
1922
1922
1922
1927
1923
1922
1922
1923
1923
1927
1922
1922
1924
1926
1922
1923
1927
1923
1923
1923
1926
1924
1922
1923
1929
1922
1923
1922
$ c
93.69
26,582.07
$ c
$ c
$ c
190.36
Markham R.P.D
412.60
Merlin R.P.D.. .
3,649.49
431.56
Milton R.P.D
5,783.96
112.85
Milverton R.P.D
4,126.27
Mitchell R.P.D
1,681.50
5,826.65
22,007.03
7,626.78
2,772.93
60.00
Newmarket R.P.D
11.32
Niagara R.P.D
Norwich R.P.D
5.00
270.00
64.16
Oil Springs R.P.D
Palmerston R.P.D
3,715.48
534.60
40.00
Petrolia R.P.D..
Preston R.P.D
9,160.16
2,183.20
3,743.01
780.02
Ridgetown R.P.D
St. Jacobs R.P.D
71.70
272.70
St. Marys R.P.D
St. Thomas R.P.D
7,765.93
80.00
17,561.83
1,945.81
61,622.41
13,072.95
24,294.55
310.00
Saltfleet R.P.D
1,753.10
Sandwich R.P.D
5,959.80
Sarnia R.P.D
150.39
Scarboro R.P.D. . .
2,140.02
Seaforth R.P.D. . .
358.05
90.00
Simcoe R.P.D.
3,311.29
8,061.14
207.31
291.86
Stamford R.P.D
2,368.71
Stratford R.P.D
Strathroy R.P.D
Streetsville R.P.D
508.48
40.00
19,271.56
7,404.43
Tavistock R.P.D..
5,967.91
182.38
Thamesville R.P.D
1,212.47
5.007.08
6,953.77
9,511.49
3,055.17
2,473.41
41,936.16
"43,190.23
15,615.02
11,761.89
183.60
Tilbury R.P.D
90.00
Tillsonburg R.P.D
Wallaceburg R.P.D
Walsingham R.P.D
Walton R.P.D
172.84
160.00
90.00
40.00
Waterdown R.P.D
1,818.84
Waterford R.P.D
738.78
346.86
170.00
Watford R.P.D.
Welland R.P.D...
9,859.53
Woodbridge R.P D
282.33
Woodstock R.P.D.
87.57
Totals
1,139,553.57
276,189.54
176,270.45
452,892.61
*For townships included in rural power districts see "Cost of Power" and "Rural Operating"
statements preceding.
1934
HYDRO-ELECTRIC POWER COMMISSION
203
SYSTEM
N.— CREDIT OR CHARGE
supplied to it to October 31, 1932, the cash receipts and payments thereon, adjustments
or Charged to each Municipality in respect of power supplied in the year
as a Credit or Charge to each Municipality at October 31, 1933
Interest at 4 % per annum
added during the year
Credited
Charged
Net amount credited or charged
in respect of power supplied in
theyearendingOctober31, 1933
Credited
Charged
Accumulated amount standing
as a credit or charge on
October 31, 1933
Credit
Charge
$ c.
3.68
$ c.
$ c.
$ c.
2,302.90
$ c.
$ c.
2,395.89
1,061.58
5,167.18
32,398.23
145.98
1,191.02
1,058.65
1,337.61
5,418.05
229.60
4,842.06
165.05
5,628.93
67.26
297.65
795.04
1,986.41
6,843.32
19,942.28
5,675.39
2,871.43
232.95
880.37
2,680.12
2,191.59
12.42
2,304.09
69.56
1,103.72
651.44
3,071.96
3,270.53
304.36
110.92
148.62
21.38
6,208.19
625.54
364.32
7,640.74
1,547.39
547.61
87.33
149.26
310.64 .
11,427.10
702.47
2,284.96
2,700.47
20,239.26
2,967.79
57,122.09
16,385.27
29,875.94
74.61
2,464.60
1,005.12
522.65
2,940.06
6,757.93
963.48
14.32
187.13
847.84
649.50
132.15
2,303.74
6,503.41
300.03
510.95
8.29
1,293.68
166.44
2,957.00
2,600.75
569.45
1,078 08
20.34
735.26
769.42
9,679.55
240.24
8,991 28
48.50
507.92
5,672.74
4,633.66
8,533.22
4,611.27
1,981.40
43,849.81
200 . 28
555.38
275.37
2,422.64
1,198.73
380.46
122.21
1,523.89
98.94
550.95
1,677.45
2,055.04
29.55
13.87
19.67
958 00
96.47
264.26
1,604.45
3,518.82
117.29
1,961.84
31,416.33
15,838.30
10,181.57
622.90
469.09
35,000.91
7,134.20
124,787.46
413,104.46
810,579.69
484,288.11
204 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
NIAGARA SYSTEM
Reserve for Renewals — October 31, 1933
Total provision for renewals to October 31, 1932 $18,065,909.62
Deduct:
Expenditures to October 31, 1932 1,436,017 .09
Balance brought forward October 31, 1932 $16,629,892.53
Added during the year ending October 31, 1933:
Amounts charged to municipalities and rural power districts
as part of the cost of power delivered to them $1,064,624.94
Amounts included in costs of distribution of power within
rural power districts 251,397.57
Provision against equipment employed in respect of contracts
with private companies which purchased power and
against equipment in local distribution systems 312,153 .93
Payments by Ottawa Valley Power Company in respect of
Chats Falls transformer station under agreement 12,141 .91
Reserve provided in respect of lines transferred to certain
rural power districts from power properties 2,070.37
Reserve provided in respect of equipment transferred 1,406.49
Interest at 4 % per annum on the monthly balances at the
credit of the account 665,334.77
2,309,129.98
$18,939,022.51
Deduct:
Expenditures during the year ending October 31, 1933 252,832 . 62
Balance carried forward October 31, 1933 $18,686,189.89
1934 HYDRO-ELECTRIC POWER COMMISSION 205
NIAGARA SYSTEM
Reserve for Obsolescence and Contingencies — October 31, 1933
Balance brought forward October 31, 1932 $12,440,735 .02
Added during the year ending October 31, 1933:
Amounts included in the costs of distribution of power within
rural power districts $125,698 . 79
Adjustment in respect of power delivered to private com-
panies in the year ending October 31, 1932 1,118.84
Payments by Ottawa Valley Power Co. in respect of Chats
Falls transformer station under agreement 13,133 .32
Share of profits realized in respect of the sale of certain of
the Commission's investment securities 44,203 . 20
Profit on English exchange in connection with
transfer of funds to London to retire
debenture stock $820,516.50
Less — Commission's share of American ex-
change paid during the year by the
Province of Ontario and by the Commis-
sion on the transfer of funds to New York
to meet capital retirements 118,008.83
Interest at 4% per annum on monthly balances
at the credit of the account 497,629.40
702,507.67
1,384,291.22
Deduct:
Interest on Commission's advances to, and
investment in the capital stock of, the
Hamilton Street Railway Company $164,220.43
in excess of profit for the year (before pro-
vision for renewal of road and equipment)
from operation of the street railway 27,307.72
$13,825,026.24
$136,912.71
Contingencies met with during the year incidental to plant
operations 272,571 . 70
Cost to the Commission (including provisions for sinking
fund $431,003.02 and renewals $312,153.93) of power
delivered to private companies and customers under
flat rate contracts in excess of the revenue received from
them 2,221,034.43
Amount appropriated to provide a reserve for the Com-
mission's claim against Dominion Government in respect
of income tax 72,334 . 46
Amount appropriated from the contingency reserve and
applied proportionately to each municipality in reduc-
tion of the cost of delivery of power thereto 2,015,572 .30
4,718,425.60
Balance carried forward October 31. 1933 $9,106,600.64
206
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
NIAGARA SYSTEM
SINKING FUND
Statement showing Sinking Fund paid by each Municipality in the periods mentioned
hereunder as part of the cost of power delivered thereto, together with
its proportionate share of other sinking funds provided out
of other revenues of the system and interest allowed
thereon to October 31, 1933
Municipality
Acton
Agincourt
Ailsa Craig. . .
Alvinston
Amherstburg. .
Ancaster twp .
Arkona
Aylmer
Ayr
Baden
Beachville. . . .
Belle River . . .
Blenheim
Blyth
Bolton
Bothwell
Brampton
Brantford . . . .
Brantford twp
Bridgeport. . . .
Brigden
Brussels
Burford
Burgessville. . .
Caledonia . . . .
Campbellville .
Cayuga
Chatham
Chippawa . . . .
Clifford
Clinton
Comber
Cottam
Courtright. . . .
Dash wood. . . .
Delaware
Dorchester. . .
Drayton
Dresden
Drumbo
Dublin
Dundas
Dunnville. . . .
Dutton
East Windsor.
Period of
years ending
Oct. 31, 1933
16 years
9 "
13 "
10 "
16 "
10 "
7 "
10 "
14 "
16 "
16 ■
11 u
13 "
10 "
13 "
13 u
17 "
14 "
10 "
6 "
11 «
10 «
13 "
12 "
16 ■
9 "
9 "
13 "
11 u
10 u
14 "
13 "
7 "
10 "
11 "
13 «
14 "
10 u
13 "
14 «
11 •
17 "
10 "
13 u
11 "
Amount
$
34,576
5,182
9,541
9,622
27,567.04
8,321.47
2,948.25
22,779.10
8,153.15
19,259.17
23,913.36
5,164.20
21,191.34
4,935.50
10,636.75
11,113.15
93,084.35
473,680.24
15,720.56
2,607.10
7,049.89
6,968.52
7,656.25
3,190.64
12,346.64
860.46
4,608.67
222,270.09
9,683.44
3,400.81
26,385.91
11,265.98
1,912.56
3,068.73
4,929.81
1,607.07
3,991.12
6,777.75
17,862.77
3,658.36
3,357.12
81,992.63
32,056.77
11,117.92
125,360.56
Municipality
Elmira
Elora
Embro
Erieau
Erie Beach
Essex
Etobicoke twp
Exeter
Fergus
Fonthill
Forest
Gait
Georgetown
Glencoe
Goderich
Granton
Guelph
Hagersville
Hamilton
Harriston
Harrow
Hensall
Hespeler
Highgate
Humberstone
Ingersoll
Jarvis
Kingsville
Kitchener
Lambeth
LaSalle
Leamington
Listowel
London
London Ry. Comn
London twp
Long Branch
Lucan
Lynden
Markham
Merlin
Merritton
Milton
Milverton
Mimico
Period of
years ending
Oct. 31, 1933
15 years
14
14
10
9
10
11
12
14
11
17
15
10
14
12
17
15
17
12
10
12
17
12
10
17
10
10
17
13
8
10
12
17
14
9
3
13
13
10
10
12
15
12
16
Amount
$ c.
46,936.38
22,693.58
6,527.33
2,938.52
747.87
15,657.28
92,232.23
23,307.91
28,771.67
2,800.14
16,729.43
313,276.52
55,732.50
10,750.22
70,410.65
4,760.53
368,952.35
47,251.46
2,173,195.35
19,021.07
11,158.25
8,596.60
56,882.64
5,893.16
9,735.62
105,017.04
7,844.51
21,171.01
704,233.55
5,287.52
6,920.00
38,294.17
40,935.07
1,276,199.72
84,384.56
7,958.96
6,340.04
11,298.71
8,470.87
9,223.04
7,210.65
51,801.81
62,216.95
27,538.79
74,423.84
934
HYDRO-ELECTRIC POWER COMMISSION
207
NIAGARA SYSTEM
SINKING FUND
Statement showing Sinking Fund paid by each Municipality in the periods mentioned
hereunder as part of the cost of power delivered thereto, together with
its proportionate share of other sinking funds provided out
of other revenues of the system and interest allowed
thereon to October 31, 1933
Municipality
Mitchell
Moorefield
Mount Brydges.
Newbury
New Hamburg. .
New Toronto . . .
Niagara Falls . . .
Niagara-on-Lake
Norwich
Oil Springs
Otterville
Palmerston
Paris
Parkhill
Petrolia
Plattsville
Point Edward. . .
Port Colborne. . .
Port Credit.
Port Dalhousie. .
Port Dover
Port Rowan ....
Port Stanley. . . .
Preston
Princeton
Queenston
Richmond Hill. .
Ridgetown
Riverside
Rockwood
Rodney
St. Catharines. .
St. Clair Beach. .
St. George
St. Jacobs
St. Marys
St. Thomas
Sandwich
Sarnia
Scarboro twp . . .
Seaforth
Simcoe
Springfield
Stamford twp. . .
Stouffville
Period of
years ending
Oct. 31, 1933
17 years
10 "
13 "
10 "
17 "
14 "
13 "
10 ■
16 u
10 "
12 "
12 "
14 "
10 "
12 «
14 "
11 "
12 "
16 "
12 "
10 "
7 "
16 "
17 "
14 "
10 "
9 "
13 "
11 "
15 "
11 "
12 u
11 *
13 «
11 "
17. "
17 u
10 "
12 "
10 "
17 "
13 «
11 u
12 "
10 ■
Amount
$ c
25,154.35
3,564.98
3,954.00
2,459.74
28,962.42
233,643.69
322,289.01
16,284.04
21,467.24
14,703.00
4,586.52
24,034.50
65,116.46
10,093.35
58,101.13
5,100.27
25,866.17
49,150.47
19,681.98
16,815.86
12,733.61
3,408.20
22,072.23
155,142.27
4,534.68
3,708.42
8,304.53
23,153.15
43,095.44
6,373.61
6,962.59
290,602.66
3,600.11
7,663.23
7,966.38
76,957.11
264,228.94
125,752.20
328,029.30
84,438.89
37,447.48
49,310.53
5,308.21
48,099.73
7,758.09
Municipality
Stratford .
Strathroy.
Sutton . . .
Tavistock .
Tecumseh
Thamesford.
Thamesville
Thedford. . .
Thorndale. .
Thorold ....
Tilbury
Tillsonburg. .
Toronto
Toronto twp.
Walkerville . .
Wallaceburg
Wardsville. .
Waterdown.
Waterford. .
Waterloo. . .
Watford
Welland...
Wellesley. . .
West Lome.
Weston
Wheatley. . .
Windsor. . . .
Woodbridge
Woodstock .
Wyoming. . .
York East twp. .
York North twp.
Zurich
Toronto Trans. Com.
Sandwich, Windsor &
Amherstburg Ry. Co.
Windsor, Essex &
Lake Shore Railway
Association
Period of
years ending
Oct. 31. 1933
17 years
14 "
10 "
12 "
11 "
14
13
10
14
11
10
14
14
17
12
9
10
11
12 "
11 «
4 "
Amount
$ c.
341,228.19
47,541.31
7,140.47
24,238 67
13,344.22
9,606.22
9,545.28
4,809.74
5,154.87
45,966.73
24,728.27
47,955.04
10,262,345.03
48,982.20
356,447.26
102,741.31
1,876.72
13,365.35
17,475.90
142,961.10
11,763.78
148,814.76
9,904.27
16,699.36
125,872.53
6,384.47
1,056,217.61
16,082.48
210,352.26
4.467.98
116,767.89
49,580.68
7,563.75
130,530.48
101,335.75
9,259.79
208
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
NIAGARA SYSTEM
SINKING FUND
Statement showing Sinking Fund paid by each Municipality in the periods mentioned
hereunder as part of the cost of power delivered thereto, together with
its proportionate share of other sinking funds provided out
of other revenues of the system and interest allowed
thereon to October 31, 1933
Period
Period
of years
of years
Rural power district*
ending
Oct. 31,
1933
Amount
Rural power district*
ending
Oct. 31,
1933
Amount
$ c.
$ c.
Acton R.P.D
6 years
405 75
London R.P.D
1 1 years
54,493.27
Ailsa Craig R.P.D
4 "
170.17
Lucan R.P.D
8 "
3,332.92
Alvinston R.P.D
5 "
202.32
Lynden R.P.D
12 "
8,580.31
Amherstburg R.P.D
10 "
25,798.26
Markham R.P.D
11 "
14,665.29
Aylmer R.P.D
12 "
12,872.68
Merlin R.P.D
5 "
6,114.96
Ayr R.P.D
8 "
1,621.95
Milton R.P.D
9 "
5,397.17
Baden R.P.D
12 "
12,436.62
Milverton R.P.D
7 "
2,540.21
Beamsville R.P.D
11 "
37,770.12
Mitchell R.P.D
8 "
7,252.84
Belle River R.P.D
11 "
12,380.64
Newmarket R.P.D
10 "
9,169.68
Blenheim R.P.D
10 "
6,342.27
Niagara R.P.D
12 "
19,264.59
Bond Lake R.P.D
10 "
28,437.76
Norwich R.P.D
9 "
16,848.79
Bothwell R.P.D
10 "
5,657.07
Oil Springs R.P.D
8 "
2,490.86
Brampton R.P.D
10 "
4,711.20
Palmerston R.P.D
7 "
1,480.01
Brant R.P.D
12 "
16,315.54
Petrolia R.P.D
11 "
1,314.67
Brigden R.P.D
7 "
2,729.97
Preston R.P.D
12 "
33,516.33
Burford R.P.D
7 "
4,853.22
Ridgetown R.P.D
12 "
16,433.13
Caledonia R.P.D
9 "
9,601.41
St. Jacobs R.P.D
11 "
10,503.65
Chatham R.P.D
12 "
18,909.14
St. Marys R.P.D
6 "
8,598.99
Chippawa R.P.D
12 "
6,281.65
St. Thomas R.P.D
11 "
23,105.95
Clinton R.P.D
6 "
5,051.52
Saltfleet R.P.D
12 "
39,176.80
Delaware R.P.D
11 "
14,701.73
Sandwich R.P.D
12 "
46,136.33
Dorchester R.P.D
12 «
20,064.21
Sarnia R.P.D
11 "
22,963.59
Dresden R.P.D
6 "
1,145.60
Scarboro R.P.D
10 "
10,388.35
Drumbo R.P.D
12 "
6,047.40
Seaforth R.P.D
6 "
1,883.47
Dundas R.P.D
12 "
19,963.40
Simcoe R.P.D
11 "
7,194.26
Dunnville R.P.D
6 "
917.32
Stamford R.P.D
12 "
6,005.06
Dutton R.P.D
8 "
3,795.94
Stratford R.P.D
10 "
8,514.34
Elmira R.P.D
8 "
1,864.68
Strathroy R.P.D
7 "
3,587.60
Elora R.P.D
8 "
4,986.77
Streetsville R.P.D
11 "
13,199.60
Essex R.P.D
9 "
10,071.77
Tavistock R.P.D
11 "
7,224.75
Exeter R.P.D
11 "
12,796.31
Thamesville R.P.D
6 "
4,152.17
Forest R.P.D
7 "
1,634.31
Tilbury R.P.D
10 "
5,252.35
Gait R.P.D
12 "
6,112.59
Tillsonburg R.P.D
10 "
19,917.27
Georgetown R.P.D
9 "
4,842.98
Wallaceburg R.P.D
11 "
12,098.06
Goderich R.P.D
9 "
3,747.23
Walsingham R.P.D
7 "
5,969.83
Grantham R.P.D
9 "
20,922.32
Walton R.P.D
9 "
4,262.46
Guelph R.P.D
9 "
10,164.29
Waterdown R.P.D
11 "
18,372.66
Haldimand R.P.D
9 "
5,674.11
Waterford R.P.D
10 "
5,891.90
Harriston R.P.D
4 "
714 81
Watford R.P.D
4 "
743.09
Harrow R.P.D
10 "
12,227.93
Welland R.P.D
12 "
53,087.00
Ingersoll R.P.D
12 "
13,565.80
Woodbridge R.P.D
11 "
28,184.12
Jordan R.P.D
12 "
8,170.83
Woodstock R.P.D
12 "
24,376.66
Keswick R.P.D
10 "
14,553.94
Total
$24,.
564,512.19
Kingsville R.P.D
10 "
32,901.03
Listowel R.P.D
7 "
4.849.35
*For townships included in rural power districts see "Cost of Power" and "Rural Operating"
statements preceding.
934 HYDRO-ELECTRIC POWER COMMISSION 209
NIAGARA SYSTEM
Reserve for Sinking Fund — October 31, 1933
Total provision for sinking fund to October 31, 1932. $21,808,954.04
Provided in the year ending October 31, 1933, in respect of:
Advances by the Province for construction of transmission
lines and stations $488,381 .90
Advances by the Province for construction of rural power
districts 66,871 .35
Advances by the Province for construction of pipe line to
Ontario Power generating station 36,923 .85
Advances by the Province for construction of Queenston-
Chippawa development 809,295 21
Bonds issued and assumed by the Commission in connection
with the purchase of the properties of the Ontario Power
Company, Toronto Power Companv, Essex system and
Thorold system 481,727 .68
Interest at 4 % per annum on amounts standing at the credit
of the reserve accounts 872,358 . 16
2,755,558.15
Total $24,564,512 . 19
210
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
NIAGARA SYSTEM— RURAL LINES
Statement showing Interest, Sinking Fund, Renewals and Contingencies charged by
the Commission to the Municipalities which operate the respective
rural lines for the year ending October 31, 1933
Operated by
Capital
cost
Interest
Sinking
fund
Renewals
Contin-
gencies
Total interest,
sinking fund,
renewals and
contingencies
charged
Milton
$ c.
15,909 84
19,617.60
$ c.
789.13
823.94
$ c.
286.38
353.12
$ c.
318.20
392.35
$ c.
159.10
196.18
$ c.
1,552 81
Welland
1,765 59
Totals
35,527.44
1,613.07
639.50
710.55
355.28
3,318.40
NIAGARA SYSTEM— RURAL LINES
Reserve for Renewals — October 31, 1933
Total provision for renewals to October 31, 1932 $5,570 . 79
Deduct:
Expenditures to October 31, 1932 288.03
Balance brought forward October 31, 1932 $5,282.76
Added during the year ending October 31, 1933:
By charges against the municipalities which operate the lines ' $710.55
Interest at 4 % per annum on monthly balances at the credit of the
account ^ 211.31
921.86
Balance carried forward October 3 1 , 1933 $6,204 . 62
1934
HYDRO-ELECTRIC POWER COMMISSION
211
NIAGARA SYSTEM— RURAL LINES
Reserve for Contingencies — October 31, 1933
Balance brought forward October 31, 1932 $2,588.80
Added during the year ending October 31, 1933:
By charges against municipalities which operate the lines $355 .28
Interest at 4 % per annum on monthly balances at the credit of the
account 103 55
— 458.83
Balance carried forward October 31, 1933 $3,047 .63
NIAGARA SYSTEM— RURAL LINES
Statement showing the total Sinking Fund paid in respect of each line, together with
interest allowed thereon to October 31, 1933
Lines operated by
Period of years
ending
October 31, 1933
Amount
Milton
20 years
21 u
$ c.
3,432.62
Welland. '. -
10,613.50
Total . . .
14,046.12
NIAGARA SYSTEM— RURAL LINES
Reserve for Sinking Fund— October 31, 1933
Total provision for sinking fund to October 31, 1932
Provided in the year ending October 31, 1933
Interest at 4 % per annum on the amount standing at the credit of the account
$12,890.98
639.50
515.64
$14,046.12
212
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
GEORGIAN BAY
Operating Account for Year
Costs of operation as provided under the terms of the Power Commission Act
Power purchased $27,316.52
Costs of operation and maintenance, including the proportion of
administrative expenses chargeable to the operation of the system :
General and transmission equipment $381,803 .94
Rural power districts 56,844 . 72
Water heater costs written off in year to extent of revenue avail-
able from water heater loads 1 ,360 . 10
440,008.76
Interest (including exchange thereon) on capital investment in:
Generation and transmission equipment $360,090.48
Rural power districts 36,600 . 19
396,690.67
Provision for renewal of:
Generation and transmission equipment $99,221 .22
Rural power districts 28,890 . 44
128,111.66
Provision for obsolescence and contingencies in respect of:
Generation and transmission equipment $28,258.29
Rural power districts 28,890 . 44
57,148.73
Provision for sinking fund:
By charges included in the cost of power delivered to munici-
palities and rural power districts $73,332 .45
By charges against contracts with private companies which
purchased power 6,507 .93
By charges included in the cost of distribution of power within
rural power districts 7,986.56
87,826.94
$1,137,103.28
GEORGIAN BAY
Statement showing the amount to be paid by each Municipality as the Cost — under
received by the Commission from each Municipality on account of such cost;
upon ascertainment (by annual adjustment) of the actual cost
Municipality
Interim rates
per
horsepower
collected by
Commission
during year
To
Jan. 1
1933
To
Oct. 31
1933
Share of
capital cost
of system
on which
interest and
fixed
charges are
payable
Average
horse-
power
supplied
in year
after cor-
rection
for power
factor
Cost of
power
pur-
chased
Share of operating
Operating,
main-
tenance
and
adminis-
trative
expenses
Interest
(including
exchange
Alliston
Arthur
Barrie
Beaver^on
Water heater load
Beeton
Bradford
Brechin
Cannington
Water heater load
Chatsworth . .
Chesley
Water heater load
$ c.
$ c.
$ c.
60.00
60.00
93,245.06
75.00
75.00
69,439.48
36.00
36.00
586,604.30
43.00
43.00
54,558.64
75.00
75.00
59,115.84
70.00
70.00
64,418.93
58.00
55.00
19,602.61
45.00
45.00
47,543.65
45.00
45.00
16,338.44
40.00
40.00
137,164.84
212
9
128
8
,251
6
179
4
1
104
7
134
51
9
153
6
3
52
3
472
2
1
6
$ c.
246.61
149.19
2,608.13
207.81
121.28
155.22
60.12
177.92
60.58
546.97
$ c.
4,160.11
3,848.78
9,559.87
3,407.74
*43.39
$ c
4,425.63
3,275.27
27,838.16
2,550.39
2,443.99
3,170.93
1,091.10
2,864.87
*13.06
2,794.71
3,045.69
914.44
2,232.49
1,185.01
6,620.21
*60.07
778.42
6,498.72
*Heater costs written off in year to extent of revenue available from heater loads.
934
HYDRO-ELECTRIC POWER COMMISSION
213
SYSTEM
Ending October 31, 1933
Revenue for period
Collected from municipalities $863,748 . 55
Power sold to private companies 62,987 . 29
Collected from customers in rural power districts 236,399.48
-$1,163,135.32
Add
Amounts due by certain municipalities, being the difference
between the sums paid and the cost of power supplied to
them in the year
Amounts due by municipalities comprising certain rural power
districts, being the difference between the revenue collected
from customers therein and the cost of power supplied to
them in the year
$5,337.24
33,035.17
38,372.41
$1,201,507.73
Deduct:
Amounts collected from certain municipalities in excess of the
sums required to be paid by them for power supplied in the
year $61,309.81
Amounts collected from customers in certain rural power districts
in excess of the cost of power delivered thereto 3,094 .64
64,404.45
Revenue $1,137,103. 28
$1,137,103.28
SYSTEM G.B.— COST OF POWER
the Power Commission Act — of Power supplied to it by the Commission; the amount
and the amount remaining to be credited or charged to each Municipality
of power supplied to it in the year ending October 31, 1933
costs and fixed charges
Cost in
excess of
revenue
from power
sold to
private
companies
Total cost
of power
for year as
provided to
be paid
under
Power
Commission
Act
Amounts
received
from
(or billed
against)
each
municipality
by the
Commission
Renewals
Obsoles-
cence and
contin-
gencies
Sinking
fund
Amounts remaining to
be credited or charged
to each municipality
upon ascertainment of
the actual cost of power
by annual adjustment
Credited 1 Charged
$ c.
1,404.09
$ c.
310.39
227.94
2,208.93
202.72
$ c.
981.00
729.57
6,173.52
573.82
$ c.
164.23
99.35
1,736.85
138.39
$ c.
11,692.06
9,438.03
76,995.12
7,783.85\
43.39]
7,207.65
8,367.51
2,663.73
6,686. 98\
13.06]
2,518.59
17,728.301
60.07(
$ c.
13,238.12
10,034.11
84,121.28
8,034.60
8,135.12
9,703.83
2,986.37
7,166.80
2,438.41
19,658.84
$ c.
1,546.06
596.08
7,126.16
207.36
927.47
1,336.32
322.64
466 . 76
$ c.
1,107.93
6,869.66
702.98
955.33
998.54
189.71
215.88
71.81
174.99
621.87
677.88
206.31
499.94
80.76
103.37
40.03
118.48
279.92
618.29
215.75
65.52
530.41
172.97
1,443.82
40.34
364.25
80.18
1,723.92
1,870.47
214
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
GEORGIAN BAY
Statement showing the amount to be paid by each Municipality as the Cost — under
received by the Commission from each Municipality on account of such cost;
upon ascertainment (by annual adjustment) of the actual cost
Municipality
Interim rates
per
horsepower
collected by
Commission
during year
To
Jan. 1
1933
To
Oct. 31
1933
Share of
capital cost
of system
on which
interest and
fixed
charges are
payable
Average
horse-
power
supplied
in year
after cor-
rection
for power
factor
Share of operating
Cost of
Operating,
power
main-
pur-
tenance
chased
and
adminis-
trative
expenses
Interest
(including
exchange)
Cold water
Water heater load
Collingwood
Water heater load
Cookstown
Creemore
Dundalk
Durham
Water heater load
Elmvale
Elmwood
Flesherton
Grand Valley
Gravenhurst
Hanover
Water heater load
Holstein
Huntsville
Water heater load
Kincardine
Water heater load
Kirkfield
Lucknow
Markdale
Water heater load
Meaford
Water heater load
Midland
Water heater load
Mildmay
Mount Forest
Neustadt
Orangeville
Water heater load
Owen Sound
Water heater load
Paisley
Penetanguishene
Water heater load
Port Elgin
Water heater load
Port McNicoll
Port Perry
$ c.
39.00
40.00
60.00
55.00
42.00
42.00
43.00
53.00
45.00
58.00
24.00
35.00
90.00
26.00
58.00
60.00
63.00
40.00
46.00
35.00
60.00
48.00
70.00
45.00
36.00
55.00
40.00
40.00
38.00
50.00
$ c.
39.00
40.00
60.00
55.00
42.00
45.00
43.00
50.00
50.00
60.00
28.00
35.00
90.00
28.00
58.00
60.00
63.00
40.00
46.00
35.00
60.00
50.00
70.00
48.00
36.00
60.00
40.00
40.00
42.00
52.00
$ c.
46,757.06
372,399.07
20,317.93
41,559.11
44,739.14
110,220.03
44,000.51
18,321.43
24,978.44
42,848.34
123,251.04
244,743.65
14,491.22
225,369.17
198,043.04
11,025.25
86,045.36
41,943.59
136,569.77
653,715.41
19,886.90
114,732.39
30,586.21
198,253.24
827,269.38
52,780.42
169,665.45
63,647.31
24,518.37
74,755.98
149.3
0.3
1,227.0
1.8
50.9
103.3
156.3
369.6
0.6
152.6
59.9
75.6
103.8
609.4
918.2
1.6
17.2
951.5
1.2
474.1
2.8
22.6
182.2
150.3
0.4
387.4
0.6
2,513.3
3.8
57.9
329.4
30.7
539.6
2.3
3,151.0
3.1
111.0
556.9
1.8
210.8
1.3
83.7
187.6
$ c.
172.94
1,421.29
58.96
119.66
181.05
428.12
176.76
69.38
87.57
120.24
1,063.59
19.92
549'. 17
26.18
211.05
174.10
448 . 74
2,911.27
67.07
381.56
35.56
625.04
3,649.96
128.58
645.08
244.18
96.95
217.30
$ c.
2,621.17
*12.88
20,534.53
*73.99
1,040.24
2,554.45
2,606.43
6,795.19
*25.48
2,711.95
1,098.39
1,561.06
2,423.38
6,055.20
11,464.66
*54. 38
826.58
12,925.53
♦37.81
8,935.70
♦147.26
553.33
3,902.32
2,337.35
♦15.16
6,342.98
♦26.98
31,788.27
♦127.44
1,088.12
6,282.25
972.24
9,854.82
♦109.80
40,295.34
♦105.40
2,283.51
7,523.41
♦68.34
3,247.57
♦52.07
1,278.15
3,801.96
$ c.
2,209.99
17,438.98
962.97
1,966.06
2,117.81
5,203.33
2,064.67
871.21
1,182.15
2,020.10
5,865.82
11,511.28
685.97
10,671.10
9,410.26
520.27
4,095.09
1,992.31
6,512.16
30,729^93
959.37
5,430.91
1,440.45
9,344.07
39,251
54
2,514
7,950
43
37
3,062
19
1,161.90
3,550.40
♦Heater costs written off in year to extent of revenue available from heater loads.
934
HYDRO-ELECTRIC POWER COMMISSION
215
SYSTEM
G.B.—COST OF POWER
the Power Commission Act — of Power supplied to it by the Commission; the amount
and the amount remaining to be credited or charged to each Municipality
of power supplied to it in the year ending October 31, 1933
costs and fixed charges
Renewals
Obsoles-
cence and
contin-
gencies
Sinking
fund
Cost in
excess of
revenue
from power
sold to
private
companies
Total cost
of power
for year as
provided to
be paid
under
Power
Commission
Act
Amounts
received
from
(or billed
against)
each
municipality
by the
Commission
Amounts remaining to
be credited or charged
to each municipality
upon ascertainment of
the actual cost of power
by annual adjustment
Credited Charged
$ c.
612.84
4,798.54
296.26
609 . 67
557.26
1,406.41
550.56
237.11
304.17
630 . 63
1,146.46
2,912.37
252.69
2.450.02
2,923.82
171.48
1,327.57
480.98
1,895.16
7,648*53
257.31
1,583.15
545.43
2,763.11
9,732.57
815.99
2,190.68
817.92
309.67
1,086.56
$ c.
183.45
1,376.63
75.29
148.20
170.60
417.51
170.33
74.13
91.05
149.48
486.22
968.62
42.45
830.21
671.68
36.65
291.96
155.63
484.18
2,388 '. 93
77.47
402.33
88.39
689.82
3,070.49
180.66
618.94
239.15
96.33
249.99
$ c.
492.18
3,919.65
213.78
438.28
470.88
1,160.15
463.14
192.85
262.94
449.89
1,295.58
2,575.96
152.57
2,370.34
2,077.72
115.95
905.85
441.52
1,437.69
6,880.74
209.34
1,207.55
322.03
2,067.48
8,702.08
555.66
1,785.74
670.00
258.08
785.09
$ c.
115.17
946.49
39.26
79.68
120.57
285.10
117.71
46.21
58.32
80.07
470.08
708.28
13.27
733.98
365.71
17.43
140.55
115.94
298.83
1,938.72
44.66
254.09
23.68
416.24
2,430.63
85.62
429.58
162.61
64.56
144.71
$ c.
6,407.741
12.881
50,436.111
73. 99 J
2,686.76
5,916.00
6,224.60
15,695
25
6,255
2,589
3,547
5,873
15,319.36
31,204.761
54.38/
1,993.45
29,981. 18\
37.81/
24,934.061
147.26/
1,441.29
10,874.39
5,697.83
15.16
17,419.74
26.98/
84,286.39/
127.44/
2,703.34
15,541.84
3,427.78
25,760.581
109.80/
107,132. 61\
105.40/
6,564.45
21,143.801
68.34/
8,443. 62 \
52.07/
3,265.64
9.836.01
$
6,049
c.
49
51,019
69
3,152
5,887
6,796
66
63
35
17,075
87
6,788.35
3,126.02
3,836.84
6,423.96
16,663
33,483
25
03
1,615
27,211
08
74
28,718
31
1,411.26
11,918.03
6,246.07
18,532
68
91,445
55
3,618
16,936
2,232
26,699
66
35
28
88
117,805
83
6,834
23,214
75
94
8,813
18
3,569
10,055
92
25
c.
509.59
465.90
571.75
1,354.58
533.23
536.74
289.58
550.17
1,343.89
2,223.89
3,636.99
1,043.64
533.08
1,085.96
7,031.72
915.32
1,394.51
829.50
10.567.82
270.30
2,002.80
317.49
304.28
219.24
$ c.
371.13
28.37
378.37
2.807.25
30.03
195.50
216
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
GEORGIAN BAY
Statement showing the amount to be paid by each Municipality as the Cost — under
received by the Commission from each Municipality on account of such cost;
upon ascertainment (by annual adjustment) of the actual cost
Municipality
Interim rates
per
horsepower
collected by
Commission
during year
To
Jan. 1
1933
To
Oct. 31
1933
Share of
capital cost
of system
on which
interest and
fixed
charges are
payable
Average
horse-
power
supplied
in year
after cor
rection
for power
factor
Cost of
power
pur-
chased
Share of operating
Operating,
main-
tenance
and
adminis-
trative
expenses
Interest
(including
exchange)
Priceville
Ripley
Rosseau
Shelburne
Water heater load
Southampton
Water heater load
Stayner
Water heater load
Sunderland
Tara
Teeswater
Thornton
Tottenham
Uxbridge
Victoria Harbour
Walkerton
Water heater load
Waubaushene
Water heater load
Wiarton
Windermere
Wingham
Woodville
$ c.
85.00
80.00
127.00
46.00
40.00
44.00
60.00
53.00
58.00
85.00
92.00
55.00
46.00
38.00
44.00
65.00
100.00
60.00
56.00
$ c.
85.00
80.00
127.00
46.00
40.00
44.00
63.00
53.00
60.00
80.00
95.00
55.00
46.00
38.00
44.00
65.00
85.00
60.00
58.00
Rural Power District
Alliston R.P.D. — Essa, Tecumseth and
Tossorontio twps
Arthur R. P. D— Luther E. and Luther
W. twps
Bala R.P.D.— Wood and Medora twp
Water heater load
Barrie R.P.D. — Innisfil, Oro and Ves-
pra twps
Water heater load
Baysville R.P.D.— Franklin, Macau-
lay, McLean, Ridout and Sherbourne
twps
Beaumaris R.P.D. — Macaulay
Monck, Muskoka and Wood and
Medora twps
Water heater load
$ c.
8,628.88
33,261.70
29,386.39
67,053.06
59,238.29
59,023.33
25,625.78
26,298.75
47,019.77
10,778.54
42,835.45
84,314.89
23,206.10
121,227.75
13,822.58
110,415.76
16,347.24
129,101.62
24,573.30
29,659.00
1,320.95
28,730.33
77,475.19
7,444.69
35,465.73
16.7
55.7
33.1
197.9
0.2
210.4
1.9
193.9
0.8
57.4
73.2
106.4
20.5
60.1
201.5
72.5
443.0
3.5
50.1
0.4
207.8
32.6
261.1
58.0
78.6
3.2
103.6
0.8
235.0
47.9
143.2
2.0
$ c.
19.34
64.52
229.24
243.71
224.60
66.49
84.79
123.25
23.75
69.62
233.41
83.98
513.15
58.03
240 . 70
302.44
67.18
91.05
3.71
120.01
272.21
$ c.
412.91
1,561.29
1,259.54
4,140.49
♦9.64
3,425.19
♦74.63
3,594.03
*34.53
1,458.23
1,262.12
2,365.42
572.45
1,639.76
4,157.92
1,222.36
6,181.93
♦126.08
1,067.31
♦17.46
5,383.18
868.99
5,587.98
1,330.18
1,276.04
67.19
1,365.73
♦28.48
3,555.02
♦4.29
1,169.02
1,730.12
♦62.22
$ c.
408.11
1,580.81
1,413.48
3,154.90
2,848.75
2,792.33
1,195.12
1,238.86
2,228.01
508.50
2,029.58
4,009.68
1,096.42
5,830.58
653.75
5,314.70
784.65
6,113.49
1,143.93
1,420.32
62.94
1,376.21
3.702.40
839.99
1,692.19
♦Heater costs written off in year to extent of revenue available from heater loads.
1934
HYDRO-ELECTRIC POWER COMMISSION
217
SYSTEM
G.B.—COST OF POWER
the Power Commission Act — -of Power supplied to it by the Commission; the amount
and the amount remaining to be credited or charged to each Municipality
of power supplied to it in the year ending October 31, 1933
costs and fixed charges
Renewals
Obsoles-
cence and
contin-
gencies
Sinking
fund
Cost in
excess of
revenue
from power
sold to
private
companies
Total cost
of power
for year as
provided to
be paid
under
Power
Commission
Act
Amounts
received
from
(or billed
against)
each
municipality
by the
Commission
Amounts remaining to
be credited or charged
to each municipality
upon ascertainment of
the actual cost of power
by annual adjustment
Credited | Charged
$ c.
135.24
545.01
515.76
907.09
730.61
761.83
388.23
367.94
710.70
171.23
726.06
1,248.08
307.63
1,350.21
168.31
1.759.69
256.42
2,018.38
365.88
423.21
19.44
325.49
1,041.68
245.35
400.28
$ c.
37.67
106.65
89.97
249.32
229.93
225.13
86.39
100.28
180.36
39.05
133.13
283.71
87.76
464.65
55.59
361.25
57.58
443.21
82.64
103.39
4.61
109.62
308.81
77.14
148.30
$ c.
90.16
350.19
309.13
702.29
623.57
621.27
269.58
276.84
495.00
113.43
450.51
885.91
244.29
1,276.03
145.50
1,162.43
172.02
1,359.15
258.49
312.07
13.87
302.33
815.29
183.57
373.35
$ c.
12.88
42.97
25.53
152.66
162.30
149.57
44.28
56.47
82.08
15.81
46.36
155.43
55.93
341.72
38.65
160.29
25.15
201.41
44.74
60.63
2.47
79.92
181.27
36.95
110.46
$ c.
1,116.31
4,251.44
3,613.41
9,535.99)
9.64/
8,264.06
74.63
8,368.76
34.53
3,508.32
3,387.30
6,184.82
1,444.22
5,095.02
10,974.14
3,098.37
15,958.271
126.081
2,187.141
17.46J
14,382.24
2,164.81
16,026.06
3.293.04
3,686.71
174.23
3,679.31
28.48
9,876.68
4.29
2,552.02
4,454.70
62.22
$ c.
1,466.36
4,625 49
4,361.26
9,438.60
8,798.42
8,867.50
3,712.00
3,993.16
6,589.41
1,712.72
5,885.69
11,500.94
3,453.27
17,602.68
2,296.04
14/042.86
2,915.47
16,326.01
3.460.29
3,686.71
174.23
3.707.79
9,880.97
2,552.02
4,516.92
$ c:
350.05
374.05
747.85
459.73
464.21
203.68
605.86
404.59
268.50
790.67
526.80
354.90
1,518.33
91.44
750.66
299.95
167.25
see page
107.03
339.38
223
218
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
GEORGIAN BAY
Statement showing the amount to be paid by each Municipality as the Cost — under
received by the Commission from each Municipality on account of such cost;
upon ascertainment (by annual adjustment) of the actual cost
Rural power district
Share of
capital cost
of system
on which
interest and
fixed
charges are
payable
Average
horse-
power
supplied
in year
after cor-
rection
for power
factor
Cost of
power
pur-
chased
Share of operating
Operating,
main-
tenance
and
adminis-
trative
expen es
Interest
(including
exchange)
Beaverton R.P.D. — Brock, Georgina,
Mara and Thorah twps
Beeton R.P.D. — Tecumseth twp...
Bradford R.P.D.— Gwillimbury W.
King and Tecumseth twps
Bruce R.P.D.— Brant, Carrick, Cul
ross, Greenock and Saugeen twps.
Water heater load
Buckskin R.P.D. — Matchedash and
Wood and Medora twps
Cannington R.P.D.— Brock, Eldon
and Mariposa twps
Chatsworth R.P.D.— Holland twp...
Cookstown R.P.D. — Essa and Innisfil
twps
Creemore R.P.D.-
prey, Sunnidale
twps ,
Nottawasaga, Os-
and Tossorontio
Elmvale R.P.D.— Flos, Medonte, Oro
and Vespra twps
Flesherton R.P.D. — Artemesia twp..
Gravenhurst R.P.D. — Muskoka twp.
Hawkestone R.P.D. — Orillia and Oro
twps
Holstein R.P.D. — Bentinck, Egremont
and Normanby twps
Huntsville R.P.D.— Brunei, Chaffey
and Franklin twps
Innisfil R.P.D. — Gwillimbury W. and
Innisfil twps
Water heater load
Lucknow R.P.D. — Kinloss twp
Mariposa R.P.D. — Brock, Mariposa
and Reach twps
Markdale R.P.D. — Artemesia, Eu-
phrasia, Glenelg and Holland twps..
St. Vincent twp.. .
-Baxter and Tay
Meaford R.P.D.-
Medonte R.P.D
twps
Water heater load
Midland R.P.D. — Tay and Tiny twps.
Neustadt R.P.D. — Bentinck twp
Nottawasaga R.P.D. — Nottawasaga
twp
41,769.58
2,145.55
20,439.71
38,289.76
5,604.47
11,810.71
3,909.54
319.32
18,556.34
19,643.14
2,556.06
5,080.26
613.46
10,803.44
69,476.44
43,455.20
10,694.49
5,683.53
5,856*59
8,339.94
129.0
3
40.9
99.9
0.1
13.8
36.0
8.7
0.8
55.0
60.0
8.0
23.0
67.7
36.4
178.4
0.3
128.6
29.6
20.6
0.2
22.9
25.9
149.42
4.40
47.38
115.71
15.98
41.70
10.08
0.93
63.71
69.50
9.27
1,567.34
206.65
148.96
34.29
23.86
26.53
30.00
2,517.95
80.49
860.38
1,653.29
*3.82
223.42
621.57
300.96
13.80
953.45
889.77
127.31
351.46
126.44
640.04
2,889.20
♦14.37
2,099.81
550.47
335.78
*7.77
342.09
473.32
2,000.80
103.15
982.12
1,842.02
267.50
552.19
187.18
15.30
891.21
937.90
120.42
241.70
25.66
518.15
3,325.29
2,053.35
512.84
272.50
280.38
387.28
*Heater costs written off in vear to extent of revenue available from heater loads.
934
HYDRO-ELECTRIC POWER COMMISSION
219
SYSTEM
G.B.—COST OF POWER
the Power Commission Act — of Power supplied to it by the Commission; the amount
and the amount remaining to be credited or charged to each Municipality
of power supplied to it in the year ending October 31, 1933
costs and fixed charges
Cost in
excess of
revenue
from power
sold to
private
companies
Total cost
of power
for year as
provided to
be paid
under
Power
Commission
Act
Amounts
received
from
(or billed
against)
each
municipality
by the
Commission
Renewals
Obsoles-
cence and
contin-
gencies
Sinking
fund
Amounts remaining to
be credited or charged
to each municipality
upon ascertainment of
the actual cost of power
by annual adjustment
Credited | Charged
$ c.
$ c.
$ c.
$ c.
$ c.
$ c.
$ c.
$ c.
556.28
34.67
155.22
6.89
439.36
22.57
99.50
2.93
5,918.53
255.10
5,918.53
255.10
see page
223
a
320.32
69.78
215.09
31.55
2,526.62
2,526.62
It
u
542.19
140.32
403.09
77.08
4,773. 70\
3.82/
683 . 14
4,777.52
a
u
82.30
24.29
59.00
10.65
683 . 14
u
a
158.26
59.41
42.84
16.90
124.20
41.16
27.77
6.71
1,568.53
622.40
1,568.53
622.40
u
u
a
it
4.66
1.18
3.36
0.62
39.85
39.85
"
*
252.37
68.39
195.32
42.43
2,466.88
2,466.88
»
u
263.32
30.44
51.84
80.34
10.18
20.52
206.77
26.91
53.41
46.28
6.17
17.74
2,493.88
330 . 70
736.67
2,493.88
330.70
736.67
u
a
a
a
a
it
12.28
3.06
6.46
52.22
1,793.46
1,793.46
a
u
u
137.36
42.67
113.65
28.08
1,479.95
1,479.95
u
It
1,003.67
249.67
731.00
137.61
8,543.091
14.37/
8,557.46
It
u
It
a
590.25
156.71
456.79
99.20
5,605.07
5,605.07
a
147.85
44.98
112.58
22.84
1,425.85
1,425.85
u
see page
It
It
it
u
it
225
69.20
22.86
59.82
15.89
799.91)
7.77/
817.42
807.68
817.42
67.70
21.41
61.65
17.66
a
it
110.88
31.45
87.78
19.98
1,140.69
1,140.69
it
220
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
GEORGIAN BAY
Statement showing the amount to be paid by each Municipality as the Cost — under
received by the Commission from each Municipality on account of such cost;
upon ascertainment (by annual adjustment) of the actual cost
Share of operating
Share of
capital cost
Average
horse-
Rural power district
of system
on which
interest and
fixed
power
supplied
in year
after cor-
Cost of
power
pur-
chased
Operating,
main-
tenance
and
Interest
(including
charges are
payable
rection
for power
factor
adminis-
trative
expenses
exchange)
$ c.
$ c
$ c.
$ c
Orangeville R.P.D. — Amaranth, Cale-
don, Erin and Garafraxa E. twps. . .
12,617.89
32.3
37.41
561.23
595.34
Owen Sound R.P.D.— Derby, Sara-
wak and Sydenham twps
6,379.75
24.3
28.15
302.77
306.99
Port Perry R.P.D. — Cartwright, Man-
vers, Reach and Scugog twps
42,916.32
105.7
122.44
2,414.01
2,046.95
Ripley R.P.D. — Huron and Kinloss
twps
4,542.12
10.1
11.70
200.33
217.69
Sauble R.P.D.— Amabel and Keppel
twps
8,671.21
16.5
19.11
377.05
417.68
Shelburne R.P.D.— Amaranth, Mel-
ancthon and Mulmur twps
9,533.54
25.7
29.77
620.45
453.96
Sparrow Lake R.P.D. — Matchedash,
Morrison, Orillia N. and Rama twps.
28,165.67
105.7
122.44
1,202.51
1,336.90
Water heater load
0.1
*3.30
Tara R.P.D. — Amabel, Arran, Derby
and Keppel twps
17,474.28
48.1
55.72
906.57
832.09
Thornton R.P.D. — Essa twp
7,285.22
13.1
15.17
336.34
349.43
Utterson R.P.D.— Cardwell, Hum-
phrey, Stephenson, Watt, and Wood
and Medora twps
20,000.39
50.7
815.82
958.68
Uxbridge R.P.D. — Brock, Georgina,
Reach, Scott and Uxbridge twps
39,501.46
93.3
108.07
1,953.15
1,882.75
Wasaga Beach R.P.D.— Flos, Notta-
wasaga and Sunnidale twps
51,169.79
168.1
194.72
2,562.45
2,426.52
Wroxeter R.P.D. — Howick, Morris
and Turnberry twps
50,996.87
97.0
112.36
2,081.30
2,433.22
To als — Municipalities. .
6,157,625.18
20,026 4
21,313.30
311,549.97
291,396.66
Water heater loads
31.3
♦1,235.85
Totals — Rural Power Districts
814,397.93
2,391.1
3,909.75
39,548.10
38,869.19
Watc heater loads
3.6
*124.25
Totals — Companies and distributing
systems
620,329.47
1,807.3
2,093.47
30,705.87
29,824.63
7,592,352.58
Non-operating capital
8,514.50
Grand totals
7,600,867.08
24,259.7
27,316.52
383,164.04
360,090.48
*Heater costs written off in vear to extent of revenue available from heater loads.
1934
HYDRO-ELECTRIC POWER COMMISSION
221
SYSTEM
G.B.—COST OF POWER
the Power Commission Act — of Power supplied to it by the Commission; the amount
and the amount remaining to be credited or charged to each Municipality
of power supplied to it in the year ending October 31, 1933
costs and fixed charges
Cost in
excess of
revenue
from power
sold to
private
companies
Total cost
of power
for year as
provided to
be paid
under
Power
Commission
Act
Amounts
received
from
(or billed
against)
each
municipality
by the
Commission
Renewals
Obsoles-
cence and
contin-
gencies
Sinking
fund
Amounts remaining to
be credited or charged
to each municipality
upon ascertainment of
the actual cost of power
by annual adjustment
Credited j Charged
$ c.
$ c.
$ c.
$ c.
$ c.
$ c.
$ c.
$ c.
180.41
45.04
131.66
24.92
1,576.01
1,576.01
see page
225
75.06
23.68
67.11
18.74
822.50
822.50
a
"
628.12
144.84
450.73
81.54
5,888.63
5,888.63
u
u
69.04
15.61
47.82
7.79
569.98
569.98
«
"
137.81
31.25
91.29
12.73
1,086.92
1,086.92
a
u
134.32
36.50
99.90
19.82
1,394.72
1,394.72
u
U
335.14
112.30
296.47
81.54
3,487. 30\
3.30/
3,490.60
a
a
245.64
117.38
70.41
26.94
183.95
76.67
37.10
10.11
2,331.48
932.04
2,331.48
932.04
a
a
a
290.43
72.06
210.48
39.11
2,386.58
2,386.58
a
u
587.12
133.68
415.06
71.97
5,151.80
5,151.80
u
u
660.46
195.17
538.61
129.67
6,707.60
6,707.60
a
a
807.05
178.96
535.05
74.82
6,222.76
6,222.76
a
a
79,625.63
22,439.34
64,767.20
15,448.03
806,540.131
1,235.85/
107,003. 41\
124.25/
62,987.29
863,748.55
107,127.66
62,987.29
61,309.81
5,337.24
11,218.68
3,047.97
8,565.25
1,844.47
8,376.91
2,770.98
6,507.93
(17,292.50)
99,221.22
28,258.29
79,840.38
977,890.93
1,033,863.50
222
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
GEORGIAN BAY SYSTEM—
Statement showing the costs of distribution of power within each Rural Power
and the amounts remaining to be credited to certain Districts or charged to
annual adjustment) of the actual costs
District and municipalities
comprised therein
Total capital cost of each district,
Provincial Government grant
received and applied thereagainst,
and the balance representing the
investment by the Commission
Total
capital
cost
Govern-
ment
grant
Com-
mission's
investment
Cost of
power
delivered
to districts
as shown
in "cost of
power"
table
preceding
Alliston R.P.D. — Essa, Tecumseth and Tos-
sorontio twps
Arthur R.P.D.— Luther E. and Luther W.
twps
Bala R.P.D.— Wood and Medora twp
Barrie R.P.D. — Innisfil, Oro and Vespra twps. .
Baysville R.P.D. — Franklin, Macaulay, Mc-
Lean, Ridout and Sherbourne twps
Beaumaris R.P.D. — Macaulay, Monck,
Muskoka, Wood and Medora twps
Beaverton R.P.D. — Brock, Georgina, Mara
and Thorah twps
Beeton R.P.D. — Tecumseth twp
Bradford R.P.D. — Gwillimbury W., King and
Tecumseth twps
Bruce R.P.D. — Brant, Carrick, Culross,
Greenock and Saugeen twps
Matchedash, Wood and
-Brock, Eldon and Mari-
Buckskin R.P.D
Medora twps
Canning ton R.P.D
posa twps
Chatsworth R.P.D.— Holland twp
Cookstown R.P.D. — Essa and Innisfil twps. . .
Creemore R.P.D. — Nottawasaga, Osprey,
Sunnidale and Tossorontio twps
Elmvale R.P.D. — Flos, Medonte, Oro and
Vespra twps
Flesherton R.P.D. — Artemesia twp
Gravenhurst R.P.D.— Muskoka twp
Hawkestone R.P.D. — Orillia and Oro twps. . . .
Holstein R.P.D. — Bentinck, Egremont and
Normanby twps
Huntsville R.P.D.— Brunei, Chaffey and
Franklin twps
Innisfil R.P.D. — Gwillimbury W. and Innisfil
twps
Lucknow R.P.D. — Kinloss twp
Mariposa R.P.D. — Brock, Mariposa and Reach
twps
Markdale R.P.D. — Artemesia, Euphrasia,
Glenelg and Holland twps
$ c
38,476.46
*4,303.91
*62,316.35
122,538.62
68,729.20
66,062.87
*57,360.58
3,018.23
37,348.15
♦58,770.96
4,078.59
♦19,300.43
1,414.37
704.54
♦45,796.11
39,707.49
♦5,286.73
4,960.99
44,823.40
1,897.34
47,521.93
78,694.24
637.09
76,123.16
♦28,470.47
$
c.
18,986
95
2,105
30,274
61,269
26
16
31
34,364
60
33,031
44
28,400
1,509
68
11
18,509
01
27,769
19
2,039
29
8,033
707
352
14
19
27
22,234.97
19,720
2,456
2,480
22,411
57
59
49
70
948
67
23,760
96
39,347
318
12
55
38,061
58
14,109
17
$
c.
19,489
51
2,198
65
32,042
19
61,269.31
34,364
60
33,031
43
28,959
90
1,509
12
18,839
14
31,001
77
2,039
30
11,267
29
707
18
352
27
23,561
14
19,986
92
2,830
14
2,480
50
22,411
70
948
67
23,760.97
39,347
12
318
54
38,061
58
14,361
30
$ c.
3,686.71
174.23
3,707.79
9,880.97
2,552.02
4,516.92
5,918.53
255.10
2,526.62
4,777.52
683 . 14
1,568.53
622.40
39.85
2,466.88
2,493.88
330 . 70
736.67
1,793.46
1,479.95
8,557.46
5,605.07
1,425.85
Note. — Items marked • include portions of transmission lines aggregating $10,279,48
used for purposes of rural power districts.
934
HYDRO-ELECTRIC POWER COMMISSION
223
RURAL POWER DISTRICTS
G.B.—R URA L OPERA TING
District, the revenues collected from (or charged to) customers within each District,
the Municipalities comprising certain other Districts upon ascertainment (by
in the year ending October 31, 1933.
Distribution costs and fixed charges
Cost of
operation,
mainten-
ance and
adminis-
tration
Interest
(including
exchange)
Renewal
charges
Obsoles-
cence and
contin-
gencies
Sinking
fund
Total
cost
Revenue
from
power and
light
customers
in each
district
Amounts remaining
to be credited to
certain districts or
charged to the
municipalities com-
prising certain other
districts
Credited
Charged
$ c
1,766.49
46.32
4,425.21
4,633.04
1,659.35
3,128.55
3,539.31
89.56
1,216.08
2,204.34
239.26
709.39
123.86
5.93
1,305.48
1,572.80
271.15
256.73
1,408.31
21.78
1,173.28
3,566.40
32.58
2,903 . 13
1,051.22
$
c.
933
.87
105
1,477
2,891
96
91
.15
1,632
80
1,491
80
1,339
72
19
67
907
95
1,232
88
88.98
543.73
34.09
16.98
1,133
15
963
135
113
1,068
95
80
22
00
44.96
970.05
1,778
15
82
19
1,813.04
659.95
$ c.
$ c.
$ c.
764.03
764.03
203.77
85.96
1,189.68
2,396.47
85.96
1,189.68
2,396.47
23.12
322.48
630.87
1,353.42
1,353.42
356.29
1,236.55
1,236.55
325.52
1,100.29
60.24
1,100.29
60.24
292.22
15.86
746.00
746.00
198.13
958.88
958.88
269.03
73.76
73.76
19.42
386.01
28.26
14.07
386.01
28.26
14.07
118.65
7.44
3.70
912.73
912.73
247.27
793.69
105.09
93.85
885.26
793.69
105.09
93.85
885.26
210.34
29.63
24.70
233.05
37.34
37.34
9.83
804.07
804.07
211.67
1,474.46
12.74
1,474.46
12.74
388.15
3.35
1,502.82
1,502.82
395.62
541.98
541.98
144.01
$ c
8,118.90
521.55
12,312.75
22,828.97
8,907.30
11,935.89
13,289.83
553.67
6,340.78
10,401.53
1,178.32
3,712.32
844.31
94.60
6,978.24
6,828.35
977.46
1,319.02
6,273.34
151.25
5,443.09
17,239.75
76.60
13,722.50
4,364.99
$ c.
8,432.03
$
313
104
c.
13
37
$ c.
625.92
9,660.41
2,652 '34
21,185.61
1,643.36
4,737.17
4,170 13
12,255.92
320
03
10,568.20
2,721.63
327.95
225.72
4,401.56
1,939.22
10,633.12
231
59
946 . 73
231.59
4,085.51
373
19
789.36
54. 95
144.54
49
94
4,868.29
2,109.95
6,595.87
232.48
826.26
151.20
1,143.58
175.44
5,247.27
1,026.07
80.25
71 00
3,674.81
1,768.28
16,796.94
442.81
51.22
25.38
14,667.67
945
17
3,567.20
797.79-
224
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
GEORGIAN BAY SYSTEM—
Statement showing the costs of distribution of power within each Rural Power
and the amounts remaining to be credited to certain Districts or charged to
annual adjustment) of the actual costs
District and municipalities
comprised therein
Total capital cost of each district,
Provincial Government grant
received and applied thereagainst,
and the balance representing the
investment by the Commission
Total
capital
cost
Govern-
ment
grant
Com-
mission's
investment
Cost of
power
delivered
to districts
as shown
in ''cost of
power"
table
preceding
Meaford R.P.D. — St. Vincent twp
Medonte R.P.D. — Baxter and Tay twps
Midland R.P.D. — Tay and Tiny twps
Neaustadt R.P.D. — Bentinck twp
Nottawasaga R.P.D. — Nottawasaga twp
Orangeville R.P.D. — Amaranth, Caledon, Erin
and Garafraxa E. twps
Owen Sound R.P.D. — Derby, Sarawak and
Sydenham twps
Port Perry R.P.D. — Cartwright, Manvers,
Reach and Scugog twps
Ripley R.P.D. — Huron and Kinloss twps
Sauble R.P.D. — Amabel and Keppel twps
Shelburne R.P.D. — Amaranth, Melancthon
and Mulmur twps
Sparrow Lake R.P.D. — Matchedash, Morrison,
Orillia N. and Rama twps
Tara R.P.D. — Amabel, Arran, Derby and
Keppel twps
Thornton R.P.D. — Essa twp
Utterson R.P.D. — Cardwell, Humphrey,
Stephenson, Watt and Wood and Medora twps.
Uxbridge R.P.D. — Brock, Georgina, Reach,
Scott and Uxbridge twps
Wasaga Beach R.P.D. — Flos, Nottawasaga
and Sunnidale twps
Wroxeter R.P.D. — Howick, Morris and Turn-
berry twps
Non-operating capital
Totals
$ c.
1,971.26
17,479.52
17,075.95
1,041.69
16,816.07
33,300.97
12,768.57
73,453.44
*8,511.30
4,338.83
26,230
75,845
30,321
9,479
'39,684.03
84,696
57,516
74,612
1,503,485.
2,872.
,506,358.32
$ c.
985.63
8,739.76
8,537.97
520.84
8,408.04
16,650.49
6,384.29
36,726.72
3,984.83
2,169.42
12,497.02
37,922.58
15,160.66
4,739.56
19,047.37
42,348.26
35,925.80
713,951.21
1,436.37
715,387.58
$ c.
985.63
8,739.76
8,537.98
520.85
8,408.03
16,650.48
6,384.28
36,726.7?
4,526.47
2,169.41
13,733.18
37,922.58
15,160.66
4,739.56
20,636.66
42,348.26
57,516.97
38,686.65
789,534.37
1,436.37
790,970.74
807.68
817.42
1,140.69
1,576.01
822.50
5,888.63
569.98
1,086.92
1,394.72
3,490.60
2,331.48
932.04
2,386.58
5,151.80
6,707.60
6,222.76
107,127.66
Note. — Items marked * include portions of transmission lines aggregating $10,279.48 used
for purposes of rural power districts.
934
HYDRO-ELECTRIC POWER COMMISSION
225
RURAL POWER DISTRICTS
G.B.—R URA L PE RA TING
District, the revenues collected from (or charged to) customers within each District,
the Municipalities comprising certain other Districts upon ascertainment (by
in the year ending October 31, 1933.
Distribution
costs and fixed charges
Cost of
operation,
mainten-
ance and
adminis-
Interest
(including
exchange)
Renewal
charges
Obsoles-
cence and
contin-
gencies
Sinking
fund
tration
Total
cost
Revenue
from
power and
light
customers
in each
district
Amounts remaining
to be credited to
certain districts or
charged to the
municipalities com-
prising certain other
districts
Credited
Charged
* c.
7.45
462.46
412.82
3.97
664.94
815.57
651.80
2,434.95
186.69
523.19
1,302.81
2,144.95
1,689.70
112.25
1,348.43
2,065.89
2,346.97
2,320.33
$ c.
46.99
411.18
411.52
24.87
404.21
802 . 25
165.15
1,722.69
209.89
100.14
656.13
1,788.64
720.06
228.71
923 64
2,029.14
2,629.08
1,859.81
$ c.
39.12
340.83
341.11
20.75
335.05
664.98
136.89
1,427.93
163.14
83.00
519.14
1,482.60
596.86
189.58
733.86
1,681.95
1,089.62
1,486.38
$ c.
39.12
340.83
341.11
20.75
335.05
664.98
136.89
1,427.93
163.14
83.00
519.14
1,482.60
596.86
189.58
733.86
1,681.95
1,089.62
1,486.38
$ c.
10.30
89.72
89.80
5.46
88.20
175.06
36.04
375.90
45.80
21.85
143.18
390.30
157.12
49.90
201.54
442.77
573.68
405.82
$ c.
142.98
2,452.70
2,413.78
75.80
2,968.14
4,698.85
1,949.27
13,278.03
1,338.64
1,898 : 10
4,535.12
10,779.69
6,092.08
1,702.06
6,327.91
13,053.50
14,436.57
13,781.48
$ c
81.20
1,747.20
1,975.37
29.47
3,188.29
3,622.89
1,382.78
11,988.36
758.98
1,356.15
2,800.73
9,701.29
5,465.83
1,272.16
6,343.24
10,006.50
14,958.31
13,407.34
220.15
15.33
521.74
$ c.
61.78
705.50
438.41
46.33
1,075.96
566.49
1,289.67
579.66
541.95
1,734.39
1,078.40
626.25
429.90
3,047.00
374.14
56,844.72
36,600.19
28,890.44
28,890.44
7,986.56
266,340.01
236,399.48
3,094.64
33,035.17
226
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
GEORGIAN BAY
Statement showing the net Credit or Charge to each Municipality in respect of power
made and interest added during the year. Also the net amount Credited
ending October 31, 1933, and the accumulated amount standing
Municipality
Date
commenced
operating
Net credit or charge at
October 31, 1932
Cash receipts and pay-
ments on account of
such credits and charges,
also adjustments made
during the year
Credit Charge
Credited | Charged
Alliston
Arthur
Barrie
Beaverton
Beeton
Bradford
Brechin
Cannington ....
Chatsworth ....
Chesley
Coldwater
Collingwood. . . .
Cookstown
Creemore
Dundalk
Durham
Elmvale
Elmwood
Flesherton
Grand Valley. . .
Gravenhurst ....
Hanover
Holstein
Huntsville
Kincardine
Kirkfield
Lucknow
Markdale
Meaford
Midland
Mildmay
Mount Forest . .
Neustadt
Orangeville
Owen Sound ....
Paisley
Penetanguishene
Port Elgin
Port McNicoll. .
Port Perry
Priceville
Ripley
Rosseau
Shelburne
Southampton. . .
June,
1918
Dec,
1916
April,
1913
Nov.,
1914
Aug.,
1918
Oct.,
1918
Jan.,
1915
Nov.,
1914
Dec,
1915
July,
1916
Mar.,
1913
Mar.,
1913
May,
1918
Nov.,
1914
Dec,
1915
Dec,
1915
June,
1913
April,
1918
Dec,
1915
Dec,
1916
Nov.,
1915
Sept.,
1916
May,
1916
Sept.,
1916
Mar.,
1921
June,
1920
Jan.,
1921
Mar.,
1916
Jan.,
1924
July,
1911
Dec,
1932
Dec,
1915
Dec,
1918
July,
1916
Dec,
1915
Sept.,
1923
July,
1911
Mar.,
1931
Jan.,
1915
Sept.,
1922
Mar.,
1920
Jan.,
1921
Tuly,
1931
luly,
1916
Feb.,
1931
$ c
1,326.03
570.36
581.97
588.52
237.63
480.20
2,305.35
538.24
455 . 16
259.75
527.83
438.90
646.92
1,918.30
2,255.17
688 . 78
1,018.49
69.42
342.62
402.13
308.38
146.87
275.51
82.22
486.70
1,550.64
10,637.05
92.27
93.64
1,758.80
211.08
741.69
2,310.44
750.90
3.035.43
209.61
"66.59
5.566.22
2,673.32
4,547.61
1.110.25
516.48
238.80
20.20
$ c
567.52
8.83
92.27
385.18
1,758.80
211.08
741.69
750.90
609.85
66.59
5,560.22
2.673.32
1,110.25
238.80
20.20
$ c
1.326.03
570.36
581.97
597.35
237.63
480.20
2,305.35
538.24
840.34
259.75
527.83
438.90
646.92
1,918.30
2,255.17
688.78
1,018.49
69.42
342.62
402.13
308.38
146.87
275.51
82.22
486.70
1934
HYDRO-ELECTRIC POWER COMMISSION
227
SYSTEM
G.B.— CREDIT OR CHARGE
supplied to it to October 31, 1932; the cash receipts and payments thereon, adjustments
or Charged to each Municipality in respect of power supplied in the year
as a Credit or Charge to each Municipality at October 31, 1933.
Interest at 4 % per annum
added during the year
Credited
Charged
Net amount credited or charged
in respect of power supplied in
the year ending October 31, 1933
Credited Charged
Accumulated amount standing
as a credit or charge on
October 31, 1933
Credit Charge
$ c.
13 51
$ c.
$ c.
1,546.06
596.08
7,126.16
207.36
927.47
1,336.32
322.64
466.76
$ c.
$ c.
1,559.57
$ c.
62.03
409.81
1,016.59
3,353.18
7 06
214.42
935.76
1,346.08
326.57
473.55
8 29
9 76
3 93
6 79
1.31
80.18
81.49
32 37
1,870.47
1,902.84
7 91
371.13
363 22
11.33
509.59
465.90
520.92
469.49
3.59
7.00
28.37
21.37
3.75
33.92
571.75
1,354.58
533.23
536.74
289.58
550.17
1,343.89
2,223.89
474.36
1,320.66
541.09
545.45
285.81
538.22
7.86
8.71
3.77
11.95
92.42
11.36
110.88
1,058.97
2,212.53
378.37
2,807.25
2,914.83
25.65
2,781.60
30.18
3,636.99
3,667.17
8.38
30.03
248.02
9.59
1,043.64
533.08
1,085.96
7,031.72
915.32
1,394.51
1,053.23
532.20
1,099.69
6,948.24
915.32
1,358.48
0.88
13.73
83.48
36.03
181.90
1,195.50
5,925.01
1.15
829.50
10,567.82
270.30
2,002.80
317.49
304.28
219.24
350.05
374.05
747.85
830.65
10,572.81
247.79
2,008.71
321.85
4.99
22.51
5.91
4.36
20.66
3.38
0.38
232.86
215.86
349.67
376.00
751.50
1.95
3.65
1.05
107.03
105.98
6.35
459.73
466.08
228
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
GEORGIAN BAY
Statement showing the net Credit or Charge to each Municipality in respect of power
made and interest added during the year. Also the net amount Credited
ending October 31, 1933, and the accumulated amount standing
Municipality
Date
commenced
operating
Net credit or charge at
October 31, 1932
Cash receipts and pay-
ments on account of
such creditsand charges,
also adjustments made
during the year
Credit
Charge
Credited | Charged
Stayner
Oct., 1913
Nov., 1914
Feb., 1918
Dec, 1920
Nov., 1918
Oct., 1918
Sept., 1922
July, 1914
Feb., 1931
Dec, 1914
May. 1931
June, 1930
Dec, 1920
Nov., 1914
Nov. 1929
Dec, 1929
Jan., 1930
Aug., 1923
July, 1932
June, 1928
Aug., 1930
Sept., 1976
Aug., 1929
Oct., 1931
July, 1928
May, 1924
Dec, 1928
Dec, 1930
Dec, 1930
Jan., 1924
Feb., 1922
June, 1929
Aug., 1930
Mar., 1929
Aug., 1931
Feb., 1928
Feb., 1924
Sept., 1923
July, 1924
Oct., 1928
July, 1930
Nov., 1930
Nov., 1926
Jan., 1922
$ c.
473.62
$ c
$ c
$ c
473.62
Sunderland
233.87
233.87
Tara
393.59
393.59
Teeswater
208.81
Thornton
273.64
273.64
Tottenham
280.14
282.48
2.34
Uxbridge
Victoria Harbour
349.36
74.58
361.19
213.14
617.71
764.13
116.38
36.72
1,565.32
349.36
74.58
Walkerton
361.19
Waubaushene
213.14
Wiarton
617.71
Windermere
764.13
Wingham
116.38
Woodville
36.72
Rural Power District*
Alliston R.P.D
80.00
Arthur R.P.D
124.67
3,160.26
4,129.32
1,639.98
1,658.96
3,701.19
178.94
1,921.23
944.11
822.76
Bala R.P.D
120.00
Barrie R.P.D
130.00
Baysville R.P.D
Beaumaris R.P.D
30.00
Beaverton R.P.D
120.00
Beeton R.P.D
Bradford R.P.D
175.86
Bruce R.P.D
20.00
Buckskin R.P.D. .
30.00
Cannington R.P.D
Chatsworth R.P.D .
1,742.48
325.63
42.08
90.00
Cooks town R.P.D
Creemore R.P.D
2,508.92
389.01
837.92
140.00
Elmvale R.P.D. .
40.00
Flesherton R.P.D
' 230 .64
Graven hurst R P D
Hawkestone R.P.D
2,665.71
79.96
2,477.26
3,071.06
74.66
HoJstein R P D
Huntsville R P.D
Innisfil R.P.D.
138.30
Lucknow R P D
Mariposa R.P.D
Markdale R P D
5,077.42
40.00
1,363.18
133.04
1,113.53
892.28
97.84
1.36
Meaford R P.D
Medonte R P D
50.00
Midland R P D
80.00
Neustadt R P D
Nottawasaga R.P.D
1,040.95
*For townships included in rural power districts see "Cost of Power" and "Rural Operating'
statements preceding.
1934
HYDRO-ELECTRIC POWER COMMISSION
229
SYSTEM
G.B. —CREDIT OR CHARGE
supplied to it to October 31, 1932; the cash receipts and payments thereon, adjustments
or Charged to each Municipality in respect of power supplied in the year
as a Credit or Charge to each Municipality at October 31, 1933.
Interest at 4% per annum
added during the year
Credited Charged
Net amount credited or charged
in respect of power supplied in
the year ending October 31, 1933
Credited
Charged
Accumulated amount standing
as a credit or charge on
October 31, 1933
Credit Charge
$ c.
6 70
$ c.
$ c.
464.21
203.68
605.86
404.59
268.50
790.67
526.80
354.90
1,518.33
91.44
$ c.
$ c.
470.91
200.17
611.90
187.43
271.29
783.06
532.58
356.00
1,524.03
95.17
$ c.
3.51
6.04
8.35
2 79
7.61
5 78
1 10
5.70
3.73
8.26
339.38
331.12
10.13
750.66
299.95
167.25
313.13
104.37
760.79
301.53
167.77
1,861.06
1.58
0.52
62.61
4.99'
126.41
165.17
65.60
66.36
148.05
7.16
77.78
37.76
32.91
25.29
2,652.34
1,643.36
4,170.13
6,059 01
6,067 85
5,875.71
320.03
1,435.29
2,721.63
225.72
1,939.22
6,690.87
411 82
4,114 09
231.59
770 28
231.59
1,117 26
69.70
373.19
2,185.37
193.71
93.70
13.03
54.95
1.68
49.94
100.36
15.56
33.52
2,109.95
232.48
151.20
175.44
1,026.07
71.00
1,768.28
442.81
25.38
4 859 23
677 05
.
1 02? 64
9.23
64.43
106.63
3.20
99.09
122.84
2.99
3 798 41
154 16
4,344 63
3 775 01
103 03
203.10
945.17
6,185.69
54.49
5.32
44.54
35.69
3.91
797.79
61.78
705.50
438.41
46.33
2 214 10
200 14
1,913.57
1,446 38
148 08
41.64
220.15
1,302.74
230
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
GEORGIAN BAY
Statement showing the net Credit or Charge to each Municipality in respect of power
made and interest added during the year. Also the net amount Credited
ending October 31, 1933, and the accumulated amount standing
Rural power district
Date
commenced
operating
Net credit or charge at
October 31, 1932
Credit Charge
Cash receipts and pay-
ments on account of
such creditsand charges,
also adjustments made
during the year
Credited | Charged
Orangeville R.P.D
Aug.,
Mar.,
Dec,
Feb.,
Oct.,
Feb.,
Oct.,
Jan.,
Aug.,
June,
Sept.,
July,
Feb.,
1927
1931
1922
1922
1931
1926
1925
1925
1930
1930
1925
1923
1929
$ c.
$ c.
3,467.39
91.36
3,644.57
1,118.90
197.64
1,867.13
$ c.
$ c.
Owen Sound R.P.D
Port Perry R.P.D
250.00
Ripley R.P.D
20.00
Sauble R.P.D
40.00
Shelburne R.P.D
180.00
Sparrow Lake R.P.D
997.46
130.48
Tara R.P.D
147.73
753.53
1,248.10
6,768.20
20.00
Thornton R.P.D
140.00
Utterson R.P.D
110.00
Uxbridge R.P.D
210.00
Wasaga Beach R.P.D
10,643.48
361.43
Wroxeter R.P.D
4,366.12
30.00
Totals
42,290.97
94,504.30
15,313.21
23,797.93
*For townships included in rural power districts see "Cost of Power" and "Rural Operating'
statements preceding.
GEORGIAN BAY SYSTEM
Reserve for Renewals— October 31, 1933
Total provision for renewals to October 31, 1932 $1,431,214. 29
Deduct:
Expenditures to October 31, 1932 133,155.81
Balance brought forward October 31, 1932 $1,298,058.48
Added during the year ending October 31, 1933:
Amounts charged to municipalities and rural power districts as
part of the cost of power delivered to them $90,844 .31
Amount included in costs of distribution of power within rural
power districts 28,890 . 44
Provision against equipment employed in respect of contracts
with private companies which purchased power, and against
equipment in local distribution systems 8,376.91
Provision for renewals on transmission lines transferred 3,531 .40
Interest at 4 % per annum on monthly balances at the credit of
the account 51.922 .34
183,565.40
$1,481,623.88
Deduct:
Expenditures during the year ending October 31 , 1933 27,403 . 29
Balance carried forward October 31, 1933 $1,454,220.59
1934
HYDRO-ELECTRIC POWER COMMISSION
23
SYSTEM
G.B.— CREDIT OR CHARGE
supplied to it to October 31, 1932; the cash receipts and payments thereon, adjustments
or Charged to each Municipality in respect of power supplied in the year
as a Credit or Charge to each Municipality at October 31, 1933.
Interest at 4 % per annum
added during the year
Credited Charged
Net amount credited or charged
in respect of power supplied in
the year ending October 31, 1933
Credited
Charged
Accumulated amount standing
as a credit or charge on
October 31, 1933
Credit
Charge
$ c.
$ c.
138.70
3.65
145.78
44.76
7.91
74.69
$ c.
$ c.
1,075.96
566.49
1,289.67
579.66
541.95
1,734.39
1,078.40
626 . 25
429.90
$ c.
$ c.
4,682.05
661.50
5,330.02
1,763.32
787.50
3,856.21
39 87
171.55
5.91
30.14
49.92
270.73
799 . 89
1,353.57
15.33
1,392.69
3,047.00
10,295.93
424.35
521.74
11,228.14
174.64
374.14
4,944.90
1,154.21
3,425.43
64,404.45
38,372.41
74,760.04
111,697.27
GEORGIAN BAY SYSTEM
Reserve for Obsolescence and Contingencies — October 31, 1933
Balance brought forward October 31, 1932 $367,197.47
Added during the year ending October 31, 1933:
Amounts charged to municipalities and rural power districts as
part of the cost of power delivered to them $25,487 .31
Amounts included in the costs of distribution of power within
rural power districts 28,890 . 44
Provision against equipment employed in respect of contracts
with private companies which purchased power and against
local distribution systems 2,770 .98
Share of profits realized in respect of the sale of certain of the
Commission's investment securities 1,304.69
Interest at 4 % per annum on monthly balances at the credit of
the account 14,687 .90
73,141.32
$440,338.79
Deduct:
Contingencies met with during the year ending October 3 1 , 1933 . . $1,311.20
Commission's share of American exchange paid during the year
by the Province of Ontario on the transfer of funds to New
York to meet capital retirements 9,191 . 27
10,502.47
Balance carried forward October 31, 1933 $429,836 .32
232
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
GEORGIAN BAY SYSTEM G.B.— SINKING FUND
Statement showing Sinking Fund paid by each Municipality in the periods mentioned
hereunder, as part of the cost of power delivered thereto, together with its
proportionate share of other sinking funds provided out of other
revenues of the system, and interest allowed thereon to
October 31, 1933
Municipality
Period
of years
ending
Oct. 31,
1933
Amount
Municipality
Period
of years
ending
Oct. 31,
1933
Amount
Alliston . .
Arthur. . .
Barrie. . . .
Beaverton
Beeton. . .
Bradford . . .
Brechin . . . .
Cannington
Chatsworth
Chesley . . . .
Coldwater. .
Collingwood
Cookstown .
Creemore. . .
Dundalk. . .
Durham
Elm vale
Elmwood. . . .
Flesherton. . .
Grand Valley
Gravenhurst .
Hanover ....
Holstein
Huntsville. . .
Kincardine . .
Kirkfield .
Lucknow .
Markdale.
Meaford. .
Midland. .
Mildmay
Mount Forest.
Neustadt
Orangeville . . .
Owen Sound . .
Paisley
Penetanguishene
Port Elgin
Port McNicoll . .
Port Perry
Priceville. . . .
Ripley
Rosseau
Shelburne. . .
Southampton
Stayner . . .
Sunderland
Tara
Teeswater .
Thornton. .
Tottenham
Uxbridge
Victoria Harbour.
10 years
12 "
15 "
14 "
10 "
10 "
14 "
14 "
13 "
12 "
15 "
15 "
10 "
14 "
13 "
13 "
15 "
10 "
13 "
12 "
13 "
12 "
12 "
12 "
9 "
9 "
9 "
12 "
9 "
15 "
1 "
13 "
10 "
12 "
13 "
9 "
17 "
3 "
14 "
9 "
9 "
9 "
3 "
12 "
3 "
15 "
14 "
10 "
9 "
10 "
10 "
9 "
14 "
$
11,295
10,746
73,212
12,230
8,727
9,628
4,761
9,119
2,277
18,843
7,205
80,932
2,675
6,686
6,385
17,853
8,963
2,053
3,628
6,573
11,934
45,822
2,093
30,684
18,529
1,744
9,186
5,032
12,735
125,095
226
16.380
5,502
21,353
101,536
5,273
36,078
1,938
3,328
7,789
838
3,882
790
10,059
1,993
8,696
6,183
4,661
6,444
1,777
5,592
8,297
3,642
YYalkerton. . . .
Waubaushene.
Wiarton. . . .
Windermere .
Wingham. . .
Woodville . .
Rural Power District*
Alliston R.P.D
Arthur R.P.D
Bala R.P.D
Barrie R.P.D
Baysville R.P.D
Beaumaris R.P.D. .
Beaverton R.P.D . . .
Beeton R.P.D
Bradford R.P.D ... .
Bruce R.P.D
Buckskin R.P.D
Cannington R.P.D.
Chatsworth R.P.D.
Cookstown R.P.D. .
Creemore R.P.D. . .
Elmvale R.P.D
Flesherton R.P.D
Gravenhurst R.P.D
Hawkestone R.P.D.
Holstein R.P.D. .. .
Huntsville R.P.D
Innisfil R.P.D
Lucknow R.P.D
Mariposa R.P.D. .. .
Markdale R.P.D .
Meaford R.P.D
Medonte R.P.D
Midland R.P.D
Neustadt R.P.D . .
Nottawasaga R.P.D
Orangeville R.P.D .
Owen Sound R.P.D
Port Perry R.P.D
Ripley R.P.D
Sauble R.P.D
Shelburne R.P.D
Sparrow Lake R.P.D
Tara R.P.D
Thornton R.P.D.
Utterson R.P.D. .
Uxbridge R.P.D. .
Wasaga Beach R.P.D
Wroxeter R.P.D. .
Total
3 years
14 "
3 "
4 "
9 "
14 "
4 years
4 "
4 "
11 "
2 "
6 "
4 "
8 "
5 "
3 "
6 "
10 "
5 "
3 "
3 "
10 "
12 "
5 "
4 "
5 "
3 "
6 "
8 "
11 "
10 "
5 "
4 "
3 "
7 "
12 "
7 "
3 "
11 "
$ c.
3,921.66
2,070.83
3,047.88
722.32
18.287.75
6,229.56
1,976.31
130.92
2,020.77
6,471.39
738.83
3,490.11
2,624.49
80.71
952.33
1,467.36
504.84
2,739.29
261.42
21.98
1,032.29
1,852.01
481.84
533.05
836.87
23.86
729.67
4,786.58
29.42
6,744.21
718.05
41.77
398.20
469.16
28.79
2,379.25
1,492.80
191.42
3,584.37
308.03
218.00
814.24
3,903.94
1,948.59
413.74
1,291.77
3,720.84
7,276.10
3,723.65
936.659.56
*For townships included in rural power districts see "Cost of Power" and "Rural Operating"
statements preceding.
934
HYDRO-ELECTRIC POWER COMMISSION
233
GEORGIAN BAY SYSTEM SINKING FUND
Reserve for Sinking Fund — October 31, 1933
Total provision for sinking fund to October 31, 1932 $816,185 .21
Provided in the year ending October 31, 1933:
By charges included in the cost of power delivered to munici-
palities and rural power districts $73,332.45
By charges included in the costs of distribution of power within
rural power districts 7,986 . 56
By charges against contracts with private companies which
purchased power and local distribution systems 6,507.93
Interest at 4 % per annum on the amount standing at the credit
of the reserve accounts 32,647 .41
120,474.35
Total $936,659.56
GEORGIAN BAY SYSTEM— RURAL LINES
Statement showing Interest, Sinking Fund, Renewals and Contingencies charged by
the Commission to the Municipalities which operate the respective
rural lines for the year ending October 31, 1933
Operated by
Capital
cost
Interest
Sinking
fund
Renewals
Contin-
gencies
Total interest,
sinking fund,
renewals and
contingencies
charged
Brechin
Flesherton
$ c.
922.02
1,885.41
$ c.
48.22
105.77
$ c.
16.60
33.94
$ c.
18.44
37.71
$ c.
9.22
18.85
$ c.
92.48
196.27
Totals
2,807.43
153.99
50.54
56.15
28.07
288.75
Statement showing the total Sinking Fund paid in respect of each line, together
with interest allowed thereon to October 31, 1933
Lines operated by
Period of years
ending
October 31, 1933
Amount
Brechin
15 years
16 "
$ c.
303 . 80
Flesherton
542.61
Total
846.41
Reserve for Sinking Fund
Total provision for sinking fund to October 31, 1932 $765 . 26
Provided in year ending October 31, 1933 —
By charges against municipalities which operate the lines $50 .54
Interest at 4 % per annum on amounts standing at the credit of the
reserve accounts 30 . 61
81.15
Total
$846.41
234 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
GEORGIAN BAY SYSTEM— RURAL LINES
Reserve for Renewals — October 31, 1933
Total provision for renewals to October 31, 1932 $443 .27
Added during the year ending October 31, 1933:
By charges against the municipalities which operate the lines $56.15
Interest at 4 % per annum on the monthly balances at the credit of
the account 17 .73
73.88
Balance carried forward October 31, 1933 $517 . 15
EASTERN ONTARIO
Operating Account for Year
Costs of operation as provided under the terms of the Power Commission Act
Power purchased $777,050.62
Costs of operation and maintenance, including the proportion of
administrative expenses chargeable to the operation of the system:
Generation, transmission and distribution equipment $634,412.70
Rural power districts 121,212.84
Water heater costs written off in year to extent of revenue
available from water heater loads 5,978 .03
761,603.57
Interest (including exchange thereon) on capital investment in:
Generation, transmission and distribution equipment $817,089.21
Rural power districts 77, 164 . 46
894,253.67
Provision for renewals of:
Generation, transmission and distribution equipment $164,867. 11
Rural power districts 62,925 .98
227,793.09
Provision for obsolescence and contingencies in respect of:
Generation, transmission and distribution equipment $51,725 .63
Rural power districts 31,462 .99
83,188.62
Provision for sinking funds:
By charges included in the cost of power delivered to munici-
palities and rural power districts $1 10,238 . 06
By charges against contracts with private companies which
purchased power and local distribution systems 45,928.35
By charges included in the cost of distribution of power within
rural power districts 16,863 .37
173,029.78
$2,916,919.35
1934 HYDRO-ELECTRIC POWER COMMISSION 235
GEORGIAN BAY SYSTEM— RURAL LINES
Reserve for Obsolescence and Contingencies — October 31, 1933
Balance brought forward October 31, 1932 $186.82
Added during the year ending October 31, 1933:
By charges against the municipalities which operate the lines $28.07
Interest at 4 % per annum on the monthly balances at the credit of
the account 7 . 47
35.54
Balance carried forward October 31, 1933 $222.36
SYSTEM
Ending October 31, 1933
Revenue for period
Collected from municipalities under "Cost" contracts at interim
monthly rates $1,859,103 .83
Collected from customers in rural power districts 470,228.73
Power sold to private companies 512,671 .12
Collected from customers in local electric distribution systems 23,922.25
Power supplied to pulp miU at Campbellford 38,785 .36
Collected from customers of the gas works 15,738 .90
$2,920,450. 19
Add:
Amounts due by certain municipalities, being the difference
between the sums paid and the cost of power supplied to
them in the year $6,720 . 97
Amounts due by municipalities comprising certain rural power
districts, being the difference between the revenue collected
from customers therein and the cost of power supplied them
in the year 38,276.43
44,997.40
$2,965,447.59
Deduct :
Amounts collected from certain municipalities in excess of the
sums required to be paid by them for power supplied in the
year $41,852.39
Amounts collected from customers in certain rural power districts
in excess of the cost of power delivered thereto 5,394.21
47,246.60
Revenue $2,918,200.99
Deduct:
Amount transferred to the credit of obsolescence and contingency
reserve, which amount comprises:
Profit from power sold to customers on local electric dis-
tribution systems owned by the Commission $3,453 .91
Shortage on operation of local gas works 2,172.27
1,281.64
$2,916,919.35
236
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
EASTERN ONTARIO
Statement showing the amount to be paid by each Municipality as the Cost — under the
received by the Commission from each Municipality on account of such cost;
pality upon ascertainment (by annual adjustment) of the actual cost
Municipality
Interim rate
per
horsepower
collected by
Commission
during year
To
Jan. 1
1933
To
Oct. 31
1933
Share of
capital cost
of system
on which
interest and
fixed charges
are payable
Average
horse-
power
supplied
in year
after
correction
for power
factor
Cost of
power
pur-
chased
Share of operating
Operating,
main-
tenance
and
adminis-
trative
expenses
Interest
(including
exchange)
Alexandria
Apple Hill
Athens
Bath
Belleville
Water heater load
Bloomfield
Bowmanville
Water heater load
Brighton
Water heater load
Brockville
Cardinal
Water heater load
Carleton Place
Water heater load
Chesterville
Cobourg
Water heater load
Colborne
Deseronto
Water heater load
Finch
Water heater load
Hastings
Havelock
Kemptville
Lakefield
Lanark
Lancaster
Lindsay
Water heater load
Madoc
Marmora
Water heater load
Martintown
Maxville
Napanee
Water heater load
Norwood
Water heater load
Oshawa
Water heater load
$ c.
64.00
60.00
55.00
105.00
35.00
60.00
37.50
42.50
31.50
37.50
35.00
44.50
37.50
39.79
54.00
67.00
55.00
47.00
42.50
46.00
50.00
97.00
42.00
49.00
49.00
55.00
75.00
37.00
41.00
38.00
$ c.
66.00
54.00
63.00
95.00
38.00
61.00
41.50
46.00
34.00
40.00
37.00
44.00
41.00
39.79
54.50
65.00
55.00
55.00
42.50
53.50
50.00
97.00
44.00
50.00
53.00
57.00
62 00
40.00
41.00
41.00
$ c
93,249.45
11,365.56
32,937.95
18,097.18
765,820.34
28,414.26
385,299.03
62,762.52
425,107
28,893
231,514.34
50,683.16
323,055.45
24,666.09
46,614.35
17,875.38
24,415.41
52,952.26
71,820.88
67.457.30
22,474.12
28,963.67
424,938.79
42,060.23
26,033.84
6,345.15
34,294.09
223,511.72
24,355.74
2,073,605.71
194.0
29.6
83.7
26.9
3,459.5
20.0
69.4
1,513.7
7.2
242.7
0.7
2,232.0
131.6
1.5
1,000.7
8.3
189.1
1,325.3
4.7
92.2
120.2
0.5
40.4
0.1
66.9
143.4
253.9
206.2
67.1
37.6
1.590.0
4.6
139.3
83.0
0.1
21.3
76.7
941.0
5.1
93.3
0.4
7,946.8
17.4
$ c.
1,551.47
236.72
669.37
215.13
27,666.63
555
12,105
01
50
1,940
94
17,849
1,052
95
44
8,002
89
1,512
10,598
28
81
737
961
35
27
323
09
535.02
1,146.81
2,030.51
1,649.04
536.62
300 . 70
12,715.69
1,114.02
663.78
170.34
613.39
7,525.45
746.15
63,552.87
$
c.
3,041
51
469
12
1,108
53
335
52
28,857
24
*728
94
1,106
30
15,594
05
*296
57
2,595
64
*29
29
15,375
35
1,639
30
*62
48
7,185
84
*307
64
1,995
89
14,511
15
*192
26
820
20
2,102
92
*29
69
748
69
*6
55
726
83
1,757
57
1,955
67
2,278
47
793
12
607
69
16,964
50
*195
33
2,045
55
1,221
81
*5
04
343
77
1,344
75
8,945
65
*199
17
1,077
98
*17
16
72,423
46
*704
08
$ c.
4,396.16
527.49
1,577.87
872.62
36,820.73
1,360
18,658
51
32
3,013
26
20,086
1,395
28,
94
10,986
25
2,346
15,594
13
73
1,195
2,245
66
82
854
03
1,178.48
2,526.85
3,420.02
3,231.60
1,070.03
1,372.21
20,400.90
2,022 .58
1,248.65
300.65
1,610. 49
10,816.85
1,164.65
99,827.38
*Heater costs written off in year to extent of revenue available from heater loads.
1934
HYDRO-ELECTRIC POWER COMMISSION
237
SYSTEM
E.O.—COST OF POWER
Power Commission Act — of Power supplied to it by the Commission; the amount
and the amount remaining to be credited or charged to each Munici-
of power supplied to it in the year ending October 31, 1933
costs and fixed charges
Cost in
excess of
revenue
from power
sold to
private
companies
Total cost
of power
for year as
provided to
be paid
under
Power
Commission
Act
Amounts
received
from
(or billed
against)
each
municipality
by the
Commission
Amounts remaining to
be credited or charged
Renewals
Obsoles-
cence and
contin-
gencies
Sinking
fund
to each municipality
upon ascertainment of
the actual cost of
power by annual ad-
justment
Credited
Charged
$ c.
1,570.30
178.81
$ c.
292.21
41.74
108.34
52.54
2,475.94
$ c.
960.27
113.81
337.19
187.57
7,678.34
$ c.
877.00
133.81
378.38
121.61
15,639.13
$ c
12,688.92
1,701.50
4,712.67
2,079.02
126,089. 43 \
728.94/
4,110.99
62,349. 97 \
296.57/
10,153. 79\
29 . 29 1
74,529. 03'
5,481.46\
62.48/
37,090.92\
307.64/
8,143.77
54,213.74)
192.26/
3,776.33
7,136.841
29.69/
2,647.42)
6.55/
3,394.89
7,494.50
10,608.81
9,826.37
3,365.51
3,358.87
67,517.57)
195.33/
6,876.00
4,185.64)
5.04/
1,094.85
4,940.74
36,749.09)
199.17/
4,002. 18\
17.16/
321,561.521
704.08/
$ c.
12,999.67
1,656.25
5,245.41
2,649.47
132,971.76
4,300.89
63,254.51
11,234.65
76,366.95
5,364.51
37,782.98
8,495.78
54,744.80
3,748.24
6,691.54
2,700.05
3,747.29
7,732.17
11,004.30
10,962.98
3,424.93
3,725.56
70,937.75
7,068.35
4,422.18
1,223.94
5,023.64
38,139.32
3,916.36
329,364.17
$ c.
310.75
$ c.
45 . 25
532.99
532.74
570.45
6,153.39
189.90
607.97
1,051.57
1,837.92
294.03
6,951.42
397.77
4,041.35
85.91
1,214.84
291.76
3,893.03
313.73
6,842.88
663.03
211.70
632.06
1,097.16
5,281.94
387.33
1,614.86
121.74
4,230.60
289.79
10,090.05
594.92
179.43
384.42
352.01
338.80
3,199.48
864.50
2,328.16
4,523.80
736.90
3,231.43
184.69
1,042.19
513.03
3,244.24
854.85
5,991.19
272.10
84.69
169.45
249.53
477.49
416.80
543.38
28.09
636.51
474.99
46.08
352.40
237.67
395.49
1,136.61
59.42
366.69
3,224.85
192.35
231.50
129.09
82.90
1,191.06
296.97
58.20
183.81
182.63
324.43
77.98
168.40
255.03
207.05
80.55
86.60
1,309.31
249.72
541.37
728.44
685 . 79
229.50
300.85
4,299.08
302.43
648.26
1,147.79
932.15
303.34
169.78
7,187.81
705.24
1,071.35
842.27
352.35
521.04
4,640.28
500 . 89
136.14
92.96
427.10
264.96
629.72
375.21
318.27
95.55
23.78
112.03
731.72
64.47
349.07
2,260.73
96.29
346.73
4,253.91
564.28
2,214.78
260.48
84.98
246.17
421.77
102.98.
7,098.57
22,345.56
6,450.31
21,037.38
35,924.56
238
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
EASTERN ONTARIO
Statement showing the amount to be paid by each Municipality as the Cost — under the
received by the Commission from each Municipality on account of such cost;
pality upon ascertainment (by annual adjustment) of the actual cost
Municipality
Interim rate
per
horsepower
collected by
Commission
during year
To
Jan. 1
1933
To
Oct. 31
1933
Share of
capital cost
of system
on which
interest and
fixed charges
are payable
Average
horse-
power
supplied
in year
after
correction
for power
factor
Cost of
power
pur-
chased
Share of operating
Operating,
main-
tenance
and
adminis-
trative
expenses
Interest
(including
exchange)
Ottawa
Ottawa
Perth
Water heater load
Peterborough
Water heater load .
Picton
Water heater load .
Port Hope
Water heater load .
Prescott
Water heater load .
Richmond
Russell
Smiths Falls
W T ater heater load .
Stirling
Water heater load
Trenton
Water heater load
Tweed
Warkworth ,
Wellington ,
Westport
Whitby
W' ater heater load
Williamsburg
W T ater heater load
Winchester
W r ater heater load
$ c
24.00
35.00
32' 00
50'00
41.50
31.00
55.00
65.00
30.00
32.00
28.50
58.00
50.00
46.00
92.84
37.00
43.00
41.00
$ c
26.90
35.00
32.66
50.00
43.20
34.00
55.00
66.00
32.00
34.50
32.20
58.00
57.00
49.00
85.00
40.00
41.00
42.00
Rural Power District
Alexandria R.P.D. — Hawkesbury E.
and Lochiel twps
Arnprior R.P.D. — Fitzroy twp
Belleville R.P.D.— H unt ingdon,
Sidney, Thurlow and Tyendinaga
twps
Water heater load
Bowmanville R.P.D. — Darlington
twp
Water heater load
Brighton R.P.D. — Brighton,
Cramahe and Murray twps
$ c
700,975.10
964.71
227,089.50
1,201,849.18
'266,394.59
259,812.38
132,447.79
19,282.81
19,603.61
251,667.22
44,456.19
502,048.94
59,966.70
20,198.40
52,293.59
38,563.79
243,824.07
30,088.99
51,431'. 71
14,920.99
66,210.36
26,816.91
5,896.11
5,430.4
18,883.0
1,107
3
5,781
48
772
6
1,067.7
3.1
746.3
1.1
48.8
44.3
1,421.3
11.2
226.1
0.5
2,699.5
4.3
147.4
61.5
165.2
61.9
942.4
5.3
155.5
0.4
217.7
0.6
30.0
293.9
0.3
102.9
0.2
22.8
$
48,011
207,712
8,855
c.
85
99
40
46,238
73
6,180
31
8,538
71
5,968
38
390
354
11,366
27
28
55
1,808
19
21,588
68
1,178
491
1,321
495
7,536
80
83
15
03
65
1,243
58
1,741
01
239
1,692
2,350
92
24
40
822
92
182
34
$ c
29,891.82
145.69
7,227.15
♦130.48
37,170.97
*1,604.76
7,551.22
♦330.03
12,322.92
*128.48
5,668.54
♦36.37
729.08
752.42
9,066.70
*356.85
1,706.36
♦16.81
15,473.23
♦133.24
2,922.67
941.84
1,794.05
1,005.75
8,320.28
♦211.55
1,477.64
♦14.48
2,145.57
♦24.05
436.60
2,375.19
♦10.97
1,106.08
♦8.42
222.21
$ c.
33,941.03
46.49
10,822.48
57,681.53
12,785 .14
12,500.31
6,269.30
928.64
930.39
11,911.17
2.143.56
24,349.05
2,889.25
966.96
2,512.74
1,859.91
11,720.54
1,423.98
2,427 '33
716.07
3,174.12
1,291.61
282.68
♦Heater costs written off in year to extent of revenue available from heater loads.
1934
HYDRO-ELECTRIC POWER COMMISSION
239
SYSTEM
E.O.—COST OF POWER
Power Commission Act — of Power supplied to it by the Commission; the amount
and the amount remaining to be credited or charged to each Munici-
of power supplied to it in the year ending October 31, 1933
costs and fixed charges
Renewals
Obsoles-
cence and
contin-
gencies
Sinking
fund
Cost in
excess of
revenue
from power
sold to
private
companies
Total cost
of power
for year as
provided to
be paid
under
Power
Commission
Act
Amounts
received
from
(or billed
against)
each
municipality
by the
Commission
Amounts remaining to
be credited or charged
to each municipality
upon ascertainment of
the actual cost of
power by annual ad-
justment
Credited
Charged
$ c
6,203.16
18.73
2,968.15
10,085.92
'3,440.16
2,609.46
1,569.48
312.57
325.40
3,019.74
344.05
3,543.21
836.12
252.83
643.54
676.87
2,596.91
368.89
712.17
252.78
614.23
287.21
62.27
$ c.
2,969.88
4.75
873.66
3,565.53
"792.78
836.69
518.26
61.79
63.80
1,000.98
134.20
1,503.46
178.41
65.05
163.39
127.28
715.57
119.36
198.51
47.70
216.15
85.73
19.89
$ c
6,784.69
10.16
2,269.89
12,017.19
2.720 ! 77
2,616.96
1,310.02
197.68
-201.58
2,494.28
443.14
4,988.56
615.17
205.29
532.92
399.29
2,466.35
294.38
517'. 78
153.77
664.71
271.22
59.38
$ c.
24,548.87
5,005.70
26,137.39
"3,493.54
4,826.68
3,373.75
220.61
200.26
6,425.17
1,022.11
12', 203 .45
666.34
278.02
746.81
279.83
4,260.24
702.96
984.14
135.62
1,328.61
465.17
103.07
$
c.
152,351
.30
207,938
.81
38,022
.431
130
48 (
192,897
261
1,604
76/
36,963
921
330
03/
44,251
731
128
481
24,677
731
36
37 f
2,840
64
2,828
13
45,284
591
356
85/
7,601
611
16
81 f
83,649
641
133
24 (
9,286
76
3,201
82
7,714
60
4,843
96
37,616.54\
211
55 (
5,630
791
14
48 f
8,726. 51\
24.05/
1,982
46
1,692
24
10,723
411
10.97/
4,329.94\
8
.42/
931
.84
$ c.
150,880.41
207,938.81
39,688.78
190,754.26
39,785.88
46,816.98
25,501.08
2,736.72
2,967.67
46,235.50
7,874.16
87,158.85
8,719.10
3,489.94
8,157.14
5,449.65
38,191.19
6,550.80
9,306.51
1,982.46
1,692.24
10,734.38
4,338.36
931.84
$ ' c.
1,535.87
2,491.93
2,436.77
786.98
139.54
594.06
255.74
3.375.97
288.12
442.54
605.69
363 . 10
905.53
555.95
see page
$ c.
,470.89
3,747.76
103.92
567.66
247
240
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
EASTERN ONTARIO
Statement showing the amount to be paid by each Municipality as the Cost — under the
received by the Commission from each Municipality on account of such cost;
pality upon ascertainment (by annual adjustment) of the actual cost
Rural power district
Share of
capital cost
of system
on which
interest and
fixed charges
are payable
Average
horse-
power
supplied
in year
after
correction
for power
factor
Cost of
power
pur-
chased
Share of operating
Operating,
main-
tenance
Interest
and
(including
adminis-
exchange)
trative
expenses
Brockville R.P.D. — Augusta, Eliza-
bethtown, Escott Front, Leeds and
Lansdowne Front, Leeds and Lans-
downe Rear, Yonge Front and
Yonge and Escott Rear twps
Water heater load
Campbellford R.P.D. — Rawdonand
Seymour twps
Carleton Place R.P.D.— Ramsay
twp
Chesterville R.P.D. — Cambridge,
Finch, Osnabruck, Russell, Wil-
liamsburg and Winchester twps.. . .
Cobourg R.P.D.— Alnwick, Haldi-
mand, Hamilton and Hope twps. . .
Water heater load
Colborne R.P.D. — Cramahe and
Haldimand twps
Fenelon Falls R.P.D.— B e x 1 e y,
Fenelon, Laxton, Digby, Longford
and Somerville twps
Water heater load
Iroquois R.P.D. — Gower S., Matilda
Mountain, Oxford, W'illiamsburg
and Winchester twps
Water heater load
Kemptville R.P.D.— Oxford twp. . .
Kingston R.P.D.— Bedford, Ernes-
town, Hinchinbrooke, Kingston,
Leedsand LansdowneFront, Lough-
brough, Oso, Pittsburgh and Port-
land twps
Water heater load
Lakefield R.P.D.— B urleigh and
Anstruther, Douro, Harvey and
Smith twps
Lindsay R.P.D. — Fenelon, Ops and
Verulam twps
Martintown R.P.D. — Charlotten-
burg and Lancaster twps
Water heater load
Maxville R.P.D. — Caledonia, Ken-
yon, Plantagenet N., Plantagenet
S. and Roxborough twps
Millbrook R.P.D. — Cavan, Manvers
and Monoghan S. Twps
*Heater costs written off in year
$ c.
60,280.04
12,150.02
57,288.75
58,271.79
30,551.99
12.745.30
54,160.94
'5,595.83
73,596.57
8,922.41
5,327.15
14,718.34
60,233.29
12.329.22
266.4
0.1
58.4
179.1
229.5
0.5
109.3
39.1
0.2
360.4
0.1
18.6
270.5
0.2
30.2
17.5
46.2
0.1
140.9
36.9
2,130.48
467.04
26.54
1,432.32
1,835.37
874.10
312.69
2,882.22
148.75
3.172.52
241.52
139.96
369.47
1,126.82
295.10
2,297.97
*3.84
347.21
1,630.24
2,369.80
*20.49
975.43
493 . 73
*9.87
2,048.18
*2.91
263.77
2,501.47
*9.19
269.84
198.85
445 . 22
*4.65
1,844.23
479.47
2,865.63
579.24
2,736.98
2,782.22
1,468.72
614.14
2,607.30
269.59
3,523.61
429.94
256.94
691.58
2,851.53
586.42
to extent of revenue available from heater loads.
1934
HYDRO- ELECTRIC POWER COMMISSION
241
SYSTEM
E.G.— COST OF POWER
Power Commission Act— of Power supplied to it by the Commission; the amount
and the amount remaining to be credited or charged to each Munici-
of power supplied to it in the year ending October 31, 1933
costs and fixed charges
Renewals
Obsoles-
cence and
contin-
gencies
Sinking
fund
Cost in
excess of
revenue
from power
sold to
private
companies
Total cost
of power
for year as
provided to
be paid
under
Power
Commission
Act
Amounts
received
from
(or billed
against)
each
municipality
by the
Commission
Amounts remaining to
be credited or charged
to each municipality
upon ascertainment of
the actual cost of
power by annual ad-
justment
Credited
Charged
818.85
102.12
882.20
609.04
346.31
160.09
566.84
85.15
812.37
105.36
64.12
228.31
982.94
154.00
225.68
39.04
202.80
192.79
106.78
43.19
211.85
20.36
236.10
27.24
17.66
54.36
204.51
42.28
605 . 13
121.49
583.68
588.10
309.62
129.89
530.72
56.89
743.59
90.62
54.17
150.90
611.24
124.38
1,204.30
264.01
809 . 65
1,037.49
494.11
176.76
1,629.24
84.08
1,222.83
136.52
"79.11
208.85
636.95
166.81
10,148. 04\
3.84/
1,920.15
26.54
8,277.87
9,414.811
20.49/
4,575.07
1,930.49
9.87
10,476.35)
2.91/
928.59
12,212. 49\
9 . 19/
1,301.04
810.81
2,148.69
4.65
8,258.22
1,848.46
$
c.
10,151
88
1,920
15
26
54
8,277
87
9,435
30
4,575
07
1,940
36
10,479
26
928
59
12,221
68
1,301
04
810
81
2,153
34
8,258
.22
1,848
.46
see page
247
242
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
EASTERN ONTARIO
Statement showing the amount to be paid by each Municipality as the Cost — under the
received by the Commission from each Municipality on account of such cost;
pality upon ascertainment (by annual adjustment) of the actual cost
Rural power district
Share of
capital cost
of system
on which
interest and
fixed charges
are payable
Average
horse-
power
supplied
in year
after
correction
for power
factor
Cost of
power
pur-
chased
Share of operating
Operating,
main-
tenance
Interest
and
(including
adminis-
exchange)
trative
expenses
Napanee R. P. D . — Camden E. , Ernes-
town, Fredericksburg S., Fredericks-
burg N., Hungerford, Portland,
Richmond, Sheffield and Tyen-
dinaga twps
Nepean R.P.D. — Clarence, Cumber-
land, Gloucester, Goulburn, Gower
N., March, Nepean and Osgoode
twps
Newcastle R.P.D. — Clarke, Darling-
ton and Manvers twps
Water heater load
Norwood R.P.D.— Asphodel, Bel-
mont and Methuen, Dummer and
Seymour twps
Omemee R.P.D. — Emily and Ops
twps
Oshawa R.P.D. — Darlington, Picker-
ing, Uxbridge, Whitby and Whitby
E. twps
Water heater load
Perth R.P.D.— Bathurst, Burgess N.,
Elmsley N., and Elmsley S. twps.. .
Peterborough R.P.D. — Cavan,
Douro, Monoghan N., Monoghan
S., Otonabee and Smith twps
Water heater load
Prescott R. P. D. — Augusta, Edwards-
burg and Matilda twps
Water heater load
Renfrew R.P.D. — Admaston and
Horton twps
Smiths Falls R.P.D.— Bastard and
Burgess S., Crosby S., Kitley, Mon-
tague and Wolford twps
Water heater load
Stirling R.P.D.— Rawdon and Sid-
ney twps
Trenton R.P.D. — Brighton, Murray
and Sidney twps
Warkworth R.P.D. — Percy twp. . . .
Wellington R.P.D. — Ameliasburg,
Athol, Hallowell, Hillier and Mur-
ray twps
Water heater load
$ c.
56,741.54
84,487 . 05
18.378.25
15,688.36
806.47
156,471.60
6,395.65
94,027.87
19,194.09
38,131.44
9,130.3:
34,461.26
738.44
52,802.53
197.8
563.4
60.6
0.3
45.1
2.4
593.1
1.1
29.8
427.9
0.8
99.4
0.1
145.2
0.1
42.7
170.7
3.0
163.0
0.4
1,581.87
4,505.67
484.64
360.67
19.19
4.743 . 19
268.56
3.422.04
988.34
612.16
1.161.20
341.48
1,365.14
23.99
1,303.57
$
c.
1,700
28
3,311
37
815
14
*o
65
486
45
23
31
6,468.67
*46.47
350
97
3,408.95
*28.67
983
65
*3
85
1,008
56
*4
17
414
85
1,536
39
13
17
1,767
*18
56
33
2,728.10
4,047.12
880.57
755.75
38.60
7,512.78
308.97
4,493.58
894.28
1.825.04
436.62
1,663.51
35.22
2,535.51
"Heater costs written off in year to extent of revenue available from heater loads.
1934
HYDRO-ELECTRIC POWER COMMISSION
243
SYSTEM
E.O.—COST OF POWER
Power Commission Act — of Power supplied to it by the Commission; the amount
and the amount remaining to be credited or charged to each Munici-
of power supplied to it in the year ending October 31, 1933
costs and fixed charges
Cost in
excess of
revenue
from power
sold to
private
companies
Total cost
of power
for year as
provided to
be paid
under
Power
Commission
Act
Amounts
received
from
(or billed
against)
each
municipality
by the
Commission
Amounts remaining to
be credited or charged
Renewals
Obsoles-
cence and
contin-
gencies
Sinking
fund
to each municipality
upon ascertainment of
the actual cost of
power by annual ad-
justment
Credited
Charged
$ c.
$ c.
$ c.
$ c.
$ c.
$ c.
$' c.
$ c.
655.34
187.54
576.26
894.18
8,323.57
8,323.57
see page
249
877.26
363.62
827.76
2,546.92
16,479.72
16,479.72
-
a
219.93
62.48
186.69
273.95
2,923. 40\
9.65/
2,223.34
2,933.05
a
a
204.60
51.87
160.12
203.88
2,223.34
u
«
10.22
2.83
8.22
10.85
113.22
113.22
a
"
1,699.15
480.49
1,587.01
2,681.18
25,172.47)
46.47/
25,218.94
u
a
85.64
24.96
64.08
134.71
1,237.89
1,237.89
«
a
846.81
289.24
942.88
1,934.58
15,338. 08\
28.67/
15,366.75
u
«
239.69
76.79
190.84
449.35
3,822. 94\
3.85/
612.16
3,826.79
ii
u
612.16
u
u
552.73
158.30
385.62
656.39
5,747.84)
4.17/
5,752.01
u
u
79.51
29.02
91.42
193.03
1,585.93
1,585.93
a
a
278.05
7.46
108.84
2.57
344.03
7.42
771.67
13.56
6,067.37
129.39
6,067.37
129.39
«
u
660.33
171.05
538.88
736.86
7,713.76)
18.33/
7,732.09
u
u
244
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
EASTERN ONTARIO
Statement showing the amount to be paid by each Municipality as the Cost — under the
received by the Commission from each Municipality on account of such cost;
pality upon ascertainment (by annual adjustment) of the actual cost
Rural power district
Share of
capital cost
of system
on which
interest and
fixed charges
are payable
Average
horse-
power
supplied
in year
after
correction
for power
factor
Cost of
power
pur-
chased
Share of operating
Operating,
main-
tenance
and
adminis-
trative
expenses
Interest
(including
exchange)
Williamsburg R. P. D.— Matilda and
Williamsburg twps
Water heater load
Totals — Municipalities
Water heater loads
Totals — Rural Power Districts
Water heater loads
Totals — Companies
Totals — Local Electric distribution
systems
Water heater loads
Totals — Local Gas distribution sys-
tem
Totals— Pulp Mill
Non-operating capital .
Campbellford Pulp Mil
Grand totals
$ c.
9.520.11
9,792,544
22
1,176,990.98
5,385,552
136,805
10
37
26,534
276,232
67
42
16,794,659.76
2,526.11
52,559.93
16,849,745.80
51.9
0.4
62,398.4
155.9
4,848.6
4.9
20,117.1
258.7
0.5
1,425.5
89,209.6
$ c.
473.22
560,301.63
"42. 397 .65
160,882.29
2,068.91
11,400.14
777,050.62
441.01
*14.45
356,287.97
♦5,761.30
43,061.56
♦195.93
201,482.46
8,677.68
♦20.80
16,632.61
8,270.42
640,390.73
$ c.
463 . 26
470 232.94
' 56.347 .23
269,208.31
6,601.23
1.278.56
13,420.94
817,089.21
♦Heater costs written off in year to extent of revenue available from heater loads.
1934
HYDRO-ELECTRIC POWER COMMISSION
245
SYSTEM
E.O.—COST OF POWER
Power Commission Act — of Power supplied to it by the Commission; the amount
and the amount remaining to be credited or charged to each Munici-
of power supplied to it in the year ending October 31, 1933
costs and fixed charges
Renewals
Obsoles-
cence and
contin-
gencies
Sinking
fund
Cost in
excess of
revenue
from power
sold to
private
companies
Total cost
of power
for year as
provided to
be paid
under
Power
Commission
Act
Amounts
received
from
(or billed
against)
each
municipality
by the
Commission
Amounts remaining to
be credited or charged
to each municipality
upon ascertainment of
the actual cost of
power by annual ad-
justment
Credited
Charged
$ c
121.8/
$ c.
39.09
$ c.
95.92
$ c.
222.42
1,856.79\
14.45/
$ c.
1,871.24
$ c.
see page
$ c.
249
103,956.49
32,333.73
98,381.41
196,716.94
13,672.78
43,170.61
1,975.79
4,042.80
14,228.82
268.95
11,856.65
42,322.28
854.98
21,906.71
(218,6?3.65)
2,091.44
851.33
2,751.09
1,818,211.11\
5,761.30/
193,285.38\
195.93/
512,671.12
20,447.541
20.80/
17,911.17
38,785.36
1,859,103.83
193,481.31
512,671.12
23,922.25
15,738.90
38,785.36
41,852.39
6,720.97
3,453.91
2,172.27f
164,867.11 51,725.63
56,166.41 2,607,289.71 2,643,702.77
I
fSurplus of $1,281.64 transferred to credit of obsolescence and contingencies reserve.
246
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
EASTERN ONTARIO SYSTEM—
Statement showing the costs of distribution of power within each Rural Power
and the amounts remaining to be credited to certain Districts or charged
(by annual adjustment) of the actual costs
District and municipalities
comprised therein
Total capital cost of each district,
Provincial Government grant
received and applied thereagainst,
and the balance representing the
investment by the Commission
Total
capital
cost
Govern-
ment
grant
Com-
mission's
investment
Cost of
power
delivered
to districts
as shown
in "cost of
power"
table
preceding
Alexandria R.P.D. — Hawkesbury E. and
Lochiel twps
Arnprior R.P.D. — Fitzroy twp
Belleville R.P.D. — Huntingdon, Sidney,
Thurlow and Tyendinaga twps
Bowmanville R.P.D. — Darlington twp
Brighton R.P.D. — Brighton, Cramahe and
Murray twps
Brockville R.P.D. — Augusta, Elizabethtown,
Escott Front, Leeds & Lansdowne Front,
Leeds & Lansdowne Rear, Yonge Front
and Yonge & Escott Rear twps
Campbellford R.P.D. — Rawdon and Sey-
mour twps
Carleton Place R.P.D. — Ramsay twp
Chesterville R.P.D.— Cambridge, Finch, Os-
nabruck, Russell, Williamsburg and Win-
chester twps
Cobourg R.P.D. — Alnwick, Haldimand,
Hamilton and Hope twps
Colborne R.P.D. — Cramahe and Haldimand
twps
Fenelon Falls R.P.D. — Bexley, Fenelon,
Laxton, Digby, Longford and Somerville
twps
Iroquois R.P.D. — Gower S., Matilda, Moun-
tain, Oxford, Williamsburg and Winchester
twps
Kemptville R.P.D.— Oxford twp
Kingston R.P.D. — Bedford, Ernestown,
Hinchinbrooke, Kingston, Leeds & Lans-
downe Front, Loughborough, Oso, Pitts-
burgh and Portland twps
Lakefield R.P.D.— Burleigh and Anstruther,
Douro, Harvey and Smith twps
Lindsay R.P.D. — Fenelon, Ops and Verulam
twps
Martintown R.P.D. — Charlottenburg and
Lancaster twps
Maxville R.P.D. — Caledonia, Kenyon, Plan-
tagenet N., Plantagenet S. and Roxborough
twps
Millbrook R.P.D. — Cavan, Manvers and
Monoghan S. twps
$
c.
27,482
12,715
78
46
148,173
41,124
49
53
14,613
69
♦221,292
88
34,908
896
83
67
*95,010
97
182,240.98
50,124
15
40,835
33
174,264
11,335
61
47
262,539
82
*47,105
86
37,461
48
49,189
50
118,216
38
29,504
34
13,741.39
6,114.10
73,407.78
20,562.27
7,306.85
108,076.28
17,454.41
448.34
45,984.45
90,384.28
25,062.08
19,993.49
86,788.95
5,520.91
127,237.90
23,442.25
18,730.74
24,594.75
59,108.19
14,468.27
$
c.
13,741
6,601
39
36
74,765
20,562
71
26
7,306
84
13,216
60
17,454
448
42
33
49,026
52
91,856
70
25,062
07
20,841
84
87,475
5,814
66
56
35,301
92
23,663
61
18,730
74
24,594
75
59,108
19
15,036.07
1,982.46
1,692.24
10,734.38
4,338.36
931.84
10,151.88
1,920.15
26.54
8,277.87
9,435.30
4,575.07
1,940.36
10,479.26
928.59
12,221.68
1,301.04
810.81
2,153.34
8,258.22
1,848.46
Note. — Items marked * include portions
for purposes of rural power districts.
of transmission lines aggregating $22,387.41 used
934
HYDRO- ELECTRIC POWER COMMISSION
247
RURAL POWER DISTRICTS
E.O.— RURAL OPERATING
District, the revenues collected from (or charged to) customers within each District,
to the Municipalities comprising certain other Districts upon ascertainment
in the year ending October 31, 1933
Distribution costs and fixed charges
Cost of
operation
mainten-
ance and
adminis-
tration
Interest
(including
exchange)
Renewal
charges
Obsoles-
cence and
contin-
gencies
Sinking
fund
Total
cost
Revenue
from power
and light
customers
in each
district
Amounts remaining
to be credited to
certain districts or
charged to the
municipalities com-
prising certain other
districts
Credited Charged
$ c.
$ c.
$ c.
$ c.
$ c.
% c.
$ c.
$ c.
$ c.
899 . 69
509.84
654 12
315.19
3,524.08
989.54
543.01
252.51
2,898.32
821.46
271.51
126.25
1,449.16
410.73
142.95
69.04
770.13
216.25
4,493.74
2,965.07
24,760.90
7,972.64
3,816.93
2,606.54
27,043.18
7,681.75
676.81
358.53
5,384.83
1,196.30
2,282.28
"290.89
534.86
351.51
291.80
145.90
76.82
2,332.73
2,712.70
379.97
10,341.41
5,341.93
4,332.92
2,166.47
1,167.39
33,502.00
32,240.06
1,261.94
2,174.41
5.16
833.60
21.47
692.00
17.84
346.00
8.92
182.17
4.70
6,148.33
84.63
4,394.17
67.21
1,754.16
17.42
4,449 . 79
2,347.39
1,887.82
943.90
512.99
18,419.76
16,357.88
2,061.88
5,062.36
4,371.32
3,599.36
1,799.68
955.28
25,223.30
23,864.99
1,358.31
2,734.24
1,184.44
983 . 25
491.63
258.84
10,227 .47
8,342.93
1,884.54
805.56
986.16
801.70
400.85
215.51
5,150.14
4,853.28
296.86
6,179.59
211.70
4,178.61
279.31
3,456.19
226.00
1,728.10
112.99
913.17
61.04
26,934.92
1,819.63
27,210.78
1,926.13
275.86
106.50
12,923.01
6,214.94
4,998.53
2,499.27
1,358.18
40,215.61
33,561.31
6,654.30
633.66
1,077.03
889.66
444.82
235.37
4,581.58
3,547.41
1,034.17
897.67
662.64
1,175.30
550.08
975.66
275.04
487.83
144.81
256.84
3,341.05
6,958.85
2,428.62
6,600.96
912.43
1,909.88
357.89
3,452.79
2,802.65
2,326.60
1,163.28
612.48
18,616.02
17,829.98
786.04
1,009.90
718.94
585.47
292.73
157.11
4,612.61
4,329.71
282.90
248
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
EASTERN ONTARIO SYSTEM—
Statement showing the costs of distribution of power within each Rural Power
and the amounts remaining to be credited to certain Districts or charged
(by annual adjustment) of the actual costs
District and municipalities
comprised therein
Total capital cost of each district,
Provincial Government grant
received and applied thereagainst,
and the balance representing the
investment by the Commission
Total
capital
cost
Govern-
ment
grant
Com-
mission's
investment
Cost of
power
delivered
to districts
as shown
in "cost of
power"
table
preceding
Napanee R.P.D. — Camden E., Ernestown,
Fredericksburg S., Fredericksburg N.,
Hungerford, Portland, Richmond, Sheffield
and Tyendinaga twps
Nepean R.P.D. — Clarence, Cumberland,
Gloucester, Goulburn, Gower N., March,
Xepean and Osgoode twps
Newcastle R.P.D. — Clark, Darlington and
Manvers twps
Norwood R.P.D. — Asphodel, Belmont and
Methuen, Dummer and Seymour twps. . . .
Omemee R.P.D. — Emily and Ops twps
Oshawa R.P.D. — Darlington, Pickering,
Uxbridge, Whitby and Whitby E. twps. . .
Perth R.P.D.— Bathurst, Burgess N., Elms-
ley N. and Elmsley S. twps
Peterborough R.P.D. — Cavan, Douro, Mon-
oghan N., Monoghan S., Otonabee and
Smith twps
Prescott R.P.D. — Augusta, Edwardsburg
and Matilda twps
Renfrew R.P.D. — Admaston and Horton
twps
Smiths Falls R.P.D.— Bastard & Burgess S.,
Crosby S., Kitley, Montague and Wolford
twps
Stirling R.P.D. — Rawdon and Sidney twps. .
Trenton R.P.D. — Brighton, Murray and
Sidney twps
Warkworth R.P.D. — Percy twp
Wellington R.P.D.— Ameliasburg, Athol,
Hallowell, Hillier and Murray twps
Williamsburg R.P.D.
Williamsburg twps
Matilda and
Non-operating capital
Totals
: 207, 552. 83
=334,380
*38,203
*18,925
3,613
279,858
28,981
177,366
75,844
7,887
117,659
*51,177
*74,143
*1.671
165,086.64
35,451.63
3,216,840.
9,465
3,226,305.45
100,977.94
162,727.79
18,170.90
9,124.47
1,806.55
136,402.87
14,490.61
88,683.13
37,741.12
3,943.59
56,935.36
23,212.00
36,978.41
648.75
82,029.95
17.725.81
1,580,026.93
4,732.72
1,584,759.65
106,574.89
171,653.18
20,032.30
9,800.61
1,806.55
143,455.35
14,490.62
88,683 . 13
38,103.31
3,943.60
60,724.53
27,965.49
37,165.19
1,022.29
83,056.69
17,725.82
,636,813.09
4,732.71
,641,545.80
8,323.57
16,479.72
2,933.05
2,223.34
113.22
25,218.94
1,237.89
15,366.75
3,826.79
612.16
5,752.01
1,585.93
6,067.37
129.39
7,732.09
1,871.24
193,481.31
Note. — Items marked * include portions of transmission lines aggregating $22,387.41 used
for purposes of rural power districts.
1934
HYDRO-ELECTRIC POWER COMMISSION
249
RURAL POWER DISTRICTS
E.O.—R URA L OPERA TING
District, the revenues collected from (or charged to) customers within each District,
to the Municipalities comprising certain other Districts upon ascertainment
in the year ending October 31, 1933
Distribution costs and fixed charges
Cost of
operation
mainten-
ance and
adminis-
tration
Interest
(including
exchange)
Renewal
charges
Obsoles-
cence and
contin-
gencies
Sinking
fund
Total
cost
Revenue
from power
and light
customers
in each
district
Amounts remaining
to be credited to
certain districts or
charged to the
municipalities com-
prising certain other
districts
Credited
Charged
5,429.16
13,796.88
1,544.04
693.28
60.86
11,934.00
859.00
6,210.32
3,482.84
129.68
5,899.20
880.63
2,231.81
102.74
5,132.78
1,508.97
5,070.74
8,163.24
964.10
467.27
87.05
6,655.94
680.70
4,200.49
1,815.57
189.20
2,908.06
1,330.66
1,786.54
47.80
3,979.96
786.97
4,097.75
6,598.33
763.09
374.40
72.26
5,384.32
565.08
3,487.00
1,499.93
157.48
2,338.31
1,009.58
1,479.37
32.21
3,283.39
653.30
2,048.89
3,299.16
381.56
187.20
36.13
2,692.17
282.54
1,743.50
749.96
78.74
1,169.16
504.79
739.67
16.11
1,641.70
326.65
1,108.13
1,783.95
210.69
102.11
19.02
1,454.55
148.76
917.95
396.77
41.46
635.51
290.80
390.42
10.44
869.76
171.98
26,078.24
50,121.28
6,796.53
4,047.60
388.54
53,339.92
3,773.97
31,926.01
11,771.86
1,208.72
18,702.25
5,602.39
12,695.18
338.69
22,639.68
5,319.11
21,821.88
46,715.75
6,039.36
3,298.91
136.63
55,689.52
2,324.57
31,146.33
10,976.47
900.53
16.949.30
4,993.37
12,405.77
294.71
19,882.59
5,236.52
2,349.60
4,256.36
3,405.53
757.17
748.69
251.91
1,449.40
779.68
795.39
308.19
1,752.95
609.02
289.41
43.98
2,757.09
82.59
121,212.84
77,164.46
62,925.98
31,462.99
16,863.37
503,110.95
470,228.73
5,394.21
38,276.43
250
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
EASTERN ONTARIO
Statement showing the net Credit or Charge to each Municipality in respect of power
made and interest added during the year. Also the net amount Credited
ending October 31, 1933, and the accumulated amount standing
Municipality
Date
commenced
operating
Net credit or charge at
October 31, 1932
Credit Charge
Cash receipts and
payments on account
of such credits and
charges, also adjust-
ments made during
the year
Credited Charged
Alexandria . . .
Apple Hill . . .
Athens
Bath
Belleville
Bloomfield . . .
Bowmanville .
Brighton
Brockville.
Cardinal
Carleton Place
Chesterville . . .
Cobourg
Colborne
Deseronto.
Finch
Hastings
Havelock
Kemptville. . . .
Lakefield
Lanark
Lancaster
Lindsay
Madoc
Marmora
Martintown . . .
Maxville
Napanee
Norwood
Oshawa
Ottawa
Perth
Peterborough . .
Picton
Port Hope
Prescott
Richmond . . . .
Russell
Smiths Falls. . .
Stirling
Trenton
Tweed
Warkworth. . . .
Wellington
West port
Jan.,
1921
April,
1921
Jan.,
1929
Nov.,
1931
April,
1929
April,
1919
Oct.,
1931
Nov.,
1929
April,
1915
July,
1930
May,
1919
April,
1914
Jan.,
1932
Jan.,
1933
Jan.,
1931
Feb.,
1928
June,
1931
Feb.,
1921
Dec,
1921
Aug.,
1920
Sept.,
1921
May,
1921
Mar.,
1928
Jan.,
1930
Jan.,
1921
May,
1921
Feb.,
1921
Nov.,
1929
Feb.,
1921
Feb.,
1929
Jan.,
1914
Feb.,
1919
Mar.,
1913
April,
1919
Nov.,
1929
Dec,
1913
Aug.,
1928
Feb.,
1926
Sept.,
1918
Jan.,
1930
Sept.,
1931
Dec,
1930
Oct.,
1923
April,
Nov..
1919
1931
$ c
694.85
242.96
64.05
366.47
5,694.08
415.50
221.82
5,456.06
314.23
3,880.22
1,140.89
2,273.76
848.06
338.15
447.41
797.30
395.44
636.74
145.56
73.66
1,580.72
2,294.36
48.52
3,572.73
13,122.41
4,492.82
75.75
431.43
263.69
293.08
4,436.46
323.51
2,427.34
454.82
815.25
1,824.91
348.49
1,065.39
5,762.49
3,378.24
9,505.06
1,597.54
993.58
203.36
1,824.91
348.49
,065.39
1,062.49
3,378.24
6.37
9,505.06
1,639.95
993.58
203.36
$ c
701.85
242.96
64.05
366.47
5,694.08
415.50
221.82
5,456.06
314.23
3,880.22
1,140.89
2,273.76
848.06
338.15
447.41
797.30
395.44
643.11
145.56
73.66
1,580.72
2,294.36
48.52
3,572.73
13,122.41
4,492.82
75.75
431.43
263.69
293.08
4,436.46
323.51
2.427.34
454.82
815.25
1934
HYDRO-ELECTRIC POWER COMMISSION
25
SYSTEM
E.O.— CREDIT OR CHARGE
supplied to it to October 31, 1932, the cash receipts and payments thereon, adjustments
or Charged to each Municipality in respect of power supplied in the year
as a Credit or Charge to each municipality at October 31, 1933
Interest at 4% per annum
added during the year
Net amount credited or charged
in respect of power supplied in
the year ending October 31, 1933
Accumulated amount standing
as a credit or charge on
October 31, 1933
Credited
Charged
Credited
Charged
Credit
Charge
$ c.
10.91
$ c.
$ c.
310.75
$ c.
$ c.
321.66
$ c.
3.38
45.25
41 87
1.02
532.74
570.45
6,153.39
189.90
607.97
1,051.57
1,837.92
533.76
575.67
6,236.38
195.36
583.97
1,054.58
1,915.74
5.22
82.99
5.46
24.00
3.01
77.82
4.44
179.43
174.99
78.46. .
384.42
352.01
338.80
462.88
369.37
338.80
17.36
28.09
474.99
28 09
12.28
462.71
5.21
46.08
352.40
237.67
395.49
1,136.61
59.42
366.69
3,224.85
192.35
231.50
129.09
82.90
1,191.06
51.29
358.82
232.13
406.15
1,119.80
65.23
6.42
5.54
10.66. .
16.81
5.81
194.40
49.98
4,527.71
3,174.87
203.03
233.91
130.07
109.94
1,221.23
10.68
2.41
0.98
27.04
30.17
0.63
102.98
102 35
133.33
40.09
7,098.57
6,965.24
1.70
1,470.89
1,466.87
52.47
1,535.87
1,588.34
175.44
3,747.76
3,572.32
67.22
2,491.93
2,436.77
786.98
2,559.15
2,437.72
793.07
0.95
6.09
5.31
103.92
98 61
5.15
139.54
594.06
255.74
3,375.97
144.69
665.53
260.21
3,407.89
71.47
4.47
31.92
22.60
4.23
567.66
590 26
288.12
442.54
605.69
283.89
448.67
617.54
6.13
11.85
252
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
EASTERN ONTARIO
Statement showing the net Credit or Charge to each Municipality in respect of power
made and interest added during the year. Also the net amount Credited
ending October 31, 1933, and the accumulated amount standing
Municipality
Date
commenced
operating
Net credit or charge at
October 31, 1932
Credit Charge
Cash receipts and
payments on account
of such credits and
charges, also adjust-
ments made during
the year
Credited Charged
Whitby
Williamsburg.
Winchester. . .
Rural Power District*
Alexandria R.P.D
Arnprior R.P.D
Belleville R.P.D
Bowmanville R.P.D
Brighton R.P.D
Brockville R.P.D
Campbellford R.P.D.
Carleton Place R.P.D.
Chesterville R.P.D.
Cobourg R.P.D
Colborne R.P.D
Fenelon Falls R.P.D.
Iroquois R.P.D
Kemptville R.P.D. .
Kingston R.P.D
Lakefield R.P.D..
Lindsay R.P.D
Martintown R.P.D.
Maxville R.P.D
Millbrook R.P.D.. .
Napanee R.P.D..
Nepean R.P.D.. .
Newcastle R.P.D.
Norwood R.P.D..
Omemee R.P.D.
Oshawa R.P.D
Perth R.P.D
Peterborough R.P.D.
Prescott R.P.D
Renfrew R.P.D
Smiths Falls R.P.D.
Stirling R.P.D
Trenton R.P.D
Warkworth R.P.D.
Wellington R.P.D...
Williamsburg R.P.D.
Totals
Jan.,
April,
Jan.,
1926
1915
1914
Dec,
1929
1930
1927
1924
1929
1921
1924
1932
1921
1927
Dec,
Aug.,
Jan.,
Nov.,
Nov.,
Aug.,
Feb.,
Nov.,
Feb.,
Aug.,
July,
July,
Dec,
Jan.,
1925
1931
1930
1930
1923
July,
July,
Jan.,
Dec.
July,
1928
1930
1922
1927
1930
Nov.,
Feb.,
Sept.
Jan.,
Jan.,
1927
1922
1927
1929
1931
April
Aug.,
Jan.,
June,
Nov.,
1918
1931
1927
1922
1930
May,
Nov.
Jan.,
Nov.
Nov.
1929
1929
1924
1928
1925
Feb.,
1923
565.44
956.53
20,815.72
966.92
2,403.74
3,448.43
2,074.59
2,600.70
7,100.68
1,883.35
37,932.98
13,643.45
2,479.47
61.92
156,014.02
$ c.
860.51
2,476.87
1,404.80
296.77
1,237.03
55.37
166.13
872.12
498.66
8,479.39
1,839.89
790.05
230.40
942.76
1,337.23
7,891.50
1,398.48
301.34
1,871.50
350.21
820.14
4,295.94
1,457^26
5,822.27
1,901.69
72,277.37
$ c
860.51
1.00
175.43
21,071.78
565.44
956.53
4.05
474.67
30.00
292.38
281.26
140.00
100.84
50.00
440.00
180.56
30.00
121.10
96.08
30.00
698.81
137.28
20.00
1,733.92
42.64
390.00
187.90
20.00
155.17
421.28
26.99
66,720.37
*For townships included in rural power districts see "Cost of Power" and "Rural Operating'
statements preceding.
934
HYDRO-ELECTRIC POWER COMMISSION
253
SYSTEM
E.O.— CREDIT OR CHARGE
supplied to it to October 31, 1932, the cash receipts and payments thereon, adjustments
or Charged to each Municipality in respect of power supplied in the year
as a Credit or Charge to each municipality at October 31, 1933
Interest at 4% per annum
added during the year
Net amount credited or charged
in respect of power supplied in
the year ending October 31, 1933
Accumulated amount standing
as a credit or charge on
October 31, 1933
Credited
Charged
Credited
Charged
Credit
Charge
$ c.
$ c.
11.50
$ c.
363.10
905.53
555.95
$ c.
$ c.
351.60
913.03
569.49
$ c.
7 50
13 54
99.17
56.19
676.81
358.53
3,256.90
1,819.52
830 21
2,282.28
23,453.54
684.71
71.33
944.68
38 68
290.89
11.87
379.97
95 26
1,261.94
1,754.16
17.42
2,061.88
1,358.31
1,884.54
296.86
49.48
2.21
3,040.67
75.00
135 64
1,240.93
659.26
82 98
7.78-
34.88
2,159.29
1,253.86
104 05
275.86
106.50
2,541.61
19.95
339.46
73.60
31.60
10.43
37.85
53.49
315.66
1.70
412.11
6,654.30
1,034.17
912.43
357.89
786.04
282.90
4,256.36
3,405.53
757.17
748.69
251.91
15.653.71
2,977.66
1,734.08
719.82
1,862.73
1,673.62
12,493.52
283 44
3,278.08
1,201.51
75 33
56.56
12.05
2,341.01
585.30
1,514.79
2,349.60
40,063 45
74.34
1,449.40
779.68
795.39
308.19
1,752.95
609.02
289.41
43.98
2,757.09
82.59
3,262.45
545.74
13,409.51
14.01
32.81
174.15
58.29
1,549.61
1,161.14
6,410.94
2,144.57
97.30
2,132.19
20.42
2.48
233.72
76.13
9,234 36
2,087 40
4,669.47
2,379.86
47,246.60
44,997.40
131,601.92
88,975.05
254 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
EASTERN ONTARIO SYSTEM
Reserve for Renewals — October 31, 1933
Total provision for renewals to October 31, 1932 $3,952,009.03
Deduct :
Expenditures to October 31, 1932 895,690.00
Balance brought forward at October 31, 1932 $3,056,319.03
Renewals reserve in respect of Nipissing district transferred to
Northern Ontario properties 215,038.84
$2,841,280.19
Added during the year ending October 31, 1933:
Amounts charged to municipalities and rural power districts as
part of the cost of power delivered to them $117,629 . 27
Amounts included in the costs of distribution of power within
rural power districts 62,925 .98
Provision against equipment employed in respect of contracts
with private companies which purchased power, and against
equipment in local distribution systems 47,237 .84
Provision against equipment in Campbellford Pulp Mill 1,051 .20
Interest at 4 % per annum on the monthly balances at the credit
of the account 1 13,614 . 69
342,458.98
$3,183,739.17
Deduct :
Expenditures during the year ending October 31, 1933 $40,199. 16
Provision for renewals on lines transferred 912 .98
41,112.14
Balance carried forward October 31, 1933 $3,142,627.03
1934 HYDRO-ELECTRIC POWER COMMISSION 255
EASTERN ONTARIO SYSTEM
Reserve for Obsolescence and Contingencies— October 31, 1933
Balance brought forward at October 31, 1932 $1,314,734. 73
Contingency reserve in respect of Nipissing district transferred to
Northern Ontario properties 186,788.89
$1,127,945.84
Added during the year ending October 31, 1933:
Amounts charged to municipalities and rural power districts as
part of the cost of power delivered to them $36,376 .53
Amount included in the costs of distribution of power within
rural power districts. * 31,462 .99
Provision against equipment employed in respect of contracts
with private companies which purchased power, and local
distribution systems 15,349 . 10
Share of profits realized in respect of the sale of certain of the
Commission's investment securities 4,671 .39
Net profit from operation of local distribution systems and
utilities 1,281 .64
Interest at 4 % per annum on monthly balances at the credit of
the account 45,117 .83
134,259.48
$1,262,205.32
Deduct:
Contingencies met with during the year ending October 31, 1933. . $121,516 .44
Commission's share of American exchange paid during the year
by the Province of Ontario on the transfer of funds to New
York to meet capital retirements 9,579 . 66
131,096.10
Balance carried forward October 31, 1933 $1,131,109. 22
256
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
EASTERN ONTARIO SYSTEM
SINKING FUND
Statement showing Sinking Fund paid by each Municipality in the periods mentioned
hereunder as part of the cost of power delivered thereto, together with its
proportionate share of other Sinking Funds, provided out of
other revenues of the system, and interest allowed
thereon to October 31, 1933
Municipality
Period
of years
ending
Oct. 31,
1933
Amount
Municipality
Period
of years
ending
Oct. 31,
1933
Amount
Alexandria. . . .
Apple Hill ...
Athens
Bath
Belleville
Bloomfield. . . .
Bowmanville. .
Brighton
Brockville. . . .
Cardinal
Carleton Place
Chesterville. . .
Cobourg
Colborne
Deseronto . . . .
Finch
Hastings
Havelock
Kemptville. . .
Lakefield
Lanark
Lancaster ....
Lindsay
Madoc'
Marmora
Martintown . .
Maxville
Napanee
Norwood
Oshawa
Ottawa
Perth
Peterborough .
Picton
Port Hope. . . .
Prescott
Richmond
Russell
Smiths Falls. .
Stirling
Trenton
Tweed
Warkworth . . .
Wellington . . .
Westport
9 years
9 "
5 "
2 "
5 "
5 "
2 "
4 "
13 "
4 "
9 "
14 "
2 "
1 "
3 "
$
17,415.
1,689.
2,458.
418.
59,864.
2,562.
11,113.
3,884.
90,546.
1,431.
40,058.
17,050.
8,067.
337.
1,951.
1,781.
788.
5,666.
9,967.
4,814.
3,115.
4,203 .
34,998.
2,479.
2,136.
1,082.
5,041.
14,478.
2,711.
186,135.
52,227.
34,151.
117,464
20,429
17,960.
25,550.
894
2,863
52,428
3,026
2 "
15,465.69
3 "
2,472.03
5 "
1,484.82
5 "
3,949.61
2 "
949.46
Whitby
Williamsburg
Winchester . .
Rural Power District 5
Alexandria R.P.D
Arnprior R.P.D
Belleville R.P.D
Bowmanville R.P.D...
Brighton R.P.D
Brockville R.P.D
Campbellford R.P.D.
Carleton Place R.P.D.
Chesterville R.P.D...
Cobourg R.P.D
Colborne R.P.D
Fenelcn Falls R.P.D.
Iroquois R.P.D
Kemptville R.P.D.. . .
Kingston R.P.D
Lakefield R.P.D
Lindsay R.P.D
Martintown R.P.D.. .
Maxville R.P.D
Millbrook R.P.D
Napanee R.P.D
Nepean R.P.D
Newcastle R.P.D
Norwood R.P.D
Omemee R.P.D
Oshawa R.P.D
Perth R.P.D
Peterborough R.P.D..
Prescott R.P.D
Renfrew R.P.D
Smiths Falls R.P.D..
Stirling R.P.D
Trenton R.P.D
Warkworth R.P.D.. .
Wellington R.P.D. .
Williamsburg R.P.D.
Total
5 years
13 "
14 "
$ c.
20,245.70
2,473.15
10,830.56
1,073.35
174.58
7,434.78
1,983.81
502.34
10,640.38
1,938.64
8.35
6,884.82
8,029.70
2,410.26
832.30
6,414.85
368.09
7,752.11
698.09
383.77
4,240.71
5,414.70
942.65
5,420.16
13,300.08
1,782.62
791.03
93.90
17,571.23
479.37
12,613.33
6,094.34
114.84
4,706.98
1,393.56
2,419.56
88 . 69
5,302.85
960.66
1,064,379.57
*For townships included in rural power districts see "Cost of Power" and "Rural Operating"
statements preceding.
1934 HYDRO-ELECTRIC POWER COMMISSION 257
EASTERN ONTARIO SYSTEM
Reserve for Sinking Fund — October 31, 1933
Total provision for sinking fund to October 31, 1932. $857,536.86
Sinking fund provision in respect of Nipissing district now transferred to Northern
Ontario properties 469 . 75
$857,067.11
Provided in the year ending October 31, 1933:
By charges included in the cost of power delivered to munici-
palities and rural power districts $110,238.06
By charges included in the costs of distribution of power within
rural power districts 16,863 .37
By charges against contracts with private companies which
purchased power, and local distribution systems 45,928.35
Interest at 4 % per annum on the amount standing at the credit
of the reserve accounts. 34,282 .68
207,312.46
Total $1,064,379 .57
258 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
THUNDER BAY
Operating Account for the Year
Costs of operation as provided for under the terms of the Power Commission Act
Costs of operation and maintenance, including the proportion of
administrative expenses chargeable to the operation of this
system :
Generation and transmission equipment $211,219.87
Rural power districts 3,509 . 95
$214,729.82
Interest (including exchange thereon) on capital investment in:
Generation and transmission equipment $970,562 . 19
Rural power districts 2,307 . 24
972,869.43
Provision for renewals of:
Generation and transmission equipment $147,780 . 23
Rural power districts 1 , 738 . 59
149,518.82
Provision for obsolescence and contingencies in respect of:
Rural power districts $869 . 29
869.29
Provision for sinking fund:
By charges included in the cost of power delivered to munici-
palities and rural power districts $105,741 .76
By charges against contracts with private companies which
purchased power 34,794 . 54
By charges included in the cost of distribution of power within
rural power districts 457 . 68
140,993.98
$1,478,981.34
1934 HYDRO-ELECTRIC POWER COMMISSION 259
SYSTEM
Ending October 31, 1933
Revenue for period
Amount received from (or billed against) each municipality by the
Commission $1 ,049,329. 42
Power sold to private companies 321,494.51
Amounts received from (or billed against) customers in rural power
districts 9,275 .86
-$1,380,099.79
Add:
Amounts due by certain municipalities, being the difference
between the sums received (or billed) at interim rates and
the amounts charged — following annual adjustment — in
respect of power supplied in the year $95,683 . 25
Amounts due by municipalities comprising certain rural power
districts, being the difference between the sums received
from (or billed against) customers therein and the amounts
charged to such districts — following annual adjustment — in
respect of power supplied in the year 3, 198 . 30
98,881.55
Revenue $1,478,981.34
$1,478,981.34
260
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
THUNDER BAY
Statement showing the amount to be paid by each Municipality as the Cost — under
received by the Commission from each Municipality on account of such cost;
tainment (by annual adjustment) of the actual cost
Municipality
Interim rate
per horsepower
collected by
Commission
during year
To
Jan. 1,
1933
To
Oct. 31,
1933
Share of
capital cost
of system
on which
interest and
fixed
charges are
payable
Average
horse-
power
supplied
in year
after cor-
rection
for power
factor
Share of operating
Operating,
main-
tenance
and
adminis-
trative
expenses
Interest
(including
exchange)
Fort William
Port Arthur
Township of Nipigon
Rural Power Districts
$21.00 plus transfor
mation charges. . .
$21.00 plus transfor
mation charges. . .
$30.00.. . .$28.00.. . .
Fort William R.P.D. — Neebing, Paipoonge
and Oliver twps
Port Arthur R.P.D. — Shuniah twp
Totals — Municipalities
Totals — Rural power districts.
Totals — Ccmpanies
Non-operating capital
Grand totals
$ c.
3,298,120.77
10,514,944.79
24,657.61
24,854.93
12,444.24
13,837,723.17
37,299.17
4,633,001.68
18,508,024.02
68,809.15
18,576,833.17
10,221.5
33,019.9
83.5
69.1
31.8
43,324.9
100.9
14,783.3
58,209.1
$ c.
39,264.12
120,311.40
1,379.54
569.80
389.65
160,955.06
959.45
49,305.36
,219.87
$ c.
173,083.04
551,451.75
1,296.81
1,314.87
609.49
725,831.60
1,924.36
242,806.23
970,562.19
THUNDER BAY SYSTEM—
Statement showing the costs of distribution of power within each Rural Power
and the amounts remaining to be credited to certain Districts or charged
(by annual adjustment) of the actual
District and municipalities
comprised therein
Total capital cost of each district,
Provincial Government grant
received and applied thereagainst,
and the balance representing the
investment by the Commission
Total
capital
cost
Govern-
ment
grant
Com-
mission's
investment
Cost of
power
delivered
to districts
as shown
in "cost of
power"
table
preceding
Fort William R.P.D. — Neebing, Oliver and
Paipoonge twps
Port Arthur R.P.D.— Shuniah twp
$ c.
60,963.67
46,914.36
$ c.
30,481.84
23,457.18
$ c.
30,481.83
23,457.18
$ c.
2,367.59
1,223.82
Totals
107,878.03
53,939.02
53,939.01
3,591.41
1934
HYDRO-ELECTRIC POWER COMMISSION
261
SYSTEM
T.B.—COST OF POWER
the Power Commission Act — of Power supplied to it by the Commission; the amount
and the amount remaining to be charged to each Municipality upon ascer-
of power supplied to it in the year ending October 31, 1933
costs and fixed charges
Renewals
Sinking
fund
Cost in
excess of
revenue
from power
sold to
private
companies
Total cost
of power
for year as
provided to
be paid
under
Power
Commission
Act
Amounts
received
from
(or billed
against)
each
municipality
by the
Commission
Amounts remaining to
be charged to each muni-
cipality upon ascertain-
ment of actual cost of
power by annual adjust-
ment
$ c.
$ c.
$ c.
$ c.
$ c.
$ c.
26,806.95
25,229.63
9,735.17
274,118.91
251,129.95
22,988.96
84,515.37
187.78
80,040.60
182.13
31,448.85
79.53
867,767.97
3,125.79
795,677.92
2,521.55
72,090.05
604 . 24
219.61
102.49
197.50
91.90
65.81
30.29
2,367.59
1,223.82
2,367.59
1,223.82
see below
111,510.10
322.10
105,452.36
289.40
34,794.54
41,263.55
96.10
. (41,359.65)
1,145,012.67
3,591.41
321,494.51
1,049,329.42
3,591.41
321,494.51
95,683.25
35,948.03
147,780.23
140,536.30
1,470,098.59
Net Charge. . .
1,374,415.34
95,683.25
95,683.25
RURAL POWER DISTRICTS
T.B.— RURAL OPERATING
District, the revenues collected from (or charged to) customers within each District,
to the Municipalities comprising certain other Districts upon ascertainment
costs in the year ending October 31, 1933
Distribution costs and fixed charges
Cost of
operation,
mainten-
ance and
adminis-
tration
Interest
(including
exchange'
Renewal
charges
Obsoles-
cence and
contin-
gencies
Sinking
fund
Total
cost
Revenue
from
power and
light
customers
in each
district
Amounts remaining
to be credited to
certain districts or
charged to the
municipalities com-
prising certain other
districts
Credited
Charged
$ c.
2,113.14
1,396.81
$ c.
1,661.95
645 . 29
$ c.
1,250.95
487.64
$ c.
625.47
243.82
$ c.
329.31
128.37
$ c.
8,348.41
4,125.75
$ c.
6,870.52
2,405.34
$ c.
$ c.
1,477.89
1,720.41
3,509.95
2,307.24
1,738.59
869 . 29
457.68
12,474.16
9,275.86
3,198.30
262
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
THUNDER BAY
Statement showing the net Credit or Charge to each Municipality in respect of power
made and interest added during the year. Also the net amount Credited
ending October 31, 1933, and the accumulated amount standing
Municipality
Date
commenced
operating
Net credit or charge
at October 31, 1932
Credit
Charge
Cash receipts and pay-
ments on account of
such credits andcharges,
also adjustments made
during the year
Credited
Charged
Fort William
Nipigon twp
Port Arthur
Oct.,
Jan.,
Dec,
Oct.,
Jan.,
1926
1925
1910
1932
1932
$ c.
891.63
$ c.
24,527.56
$ c.
24,527.56
$ c.
891.63
137,165.48
123.34
137,165.48
Rural Power Districts*
Fort William R.P.D
40.00
Port Arthur R.P.D
0.88
Totals
892.51
161,816.38
161,693.04
931.63
*For townships included in rural power districts see "Cost of Power" and "Rural Operating"
statements preceding.
THUNDER BAY SYSTEM
Reserve for Renewals — October 31, 1933
Total provision for renewals to October 31, 1932 $1,144,179.30
Deduct:
Expenditures to October 31, 1932 3,656.90
Balance brought forward October 31, 1932. $1,140,522.40
Added during the year ending October 31, 1933:
Amounts charged to municipalities and rural power districts as
part of the cost of power delivered to them $111,832.20
Amounts included in the costs of distribution of power within
rural power districts 1,738.59
Provision against equipment employed in respect of contracts
with private companies which purchased power 35,948.03
Reserve provided in respect of equipment transferred 793 . 19
Interest at 4 % per annum on monthly balances at the credit of
the account 45,650.65
195,962.66
$1,336,485.06
Deduct:
Expenditures during the year ending October 31, 1933 11,165 .57
Balance carried forward October 31, 1933 $1,325,319.49
1934
HYDRO-ELECTRIC POWER COMMISSION
263
SYSTEM
T.B.— CREDIT OR CHARGE
supplied to it to October 31, 1932, the cash receipts and payments thereon, adjustments
or Charged to each Municipality in respect of power supplied in the year
as a Credit or Charge to each Municipality at October 31, 1933
Interest at \ ( " ( per annum
added during the year
Net amount credited or charged
in respect of power supplied in
the year ending October 31, 1933
Accumulated amount standing
as a credit or charge on
October 31, 1933
Credited
Charged
Credited
Charged
Credit
Charge
$ c.
$ c.
376.31
$ c.
$ c.
22,988.96
604 . 24
72,090.05
1,477.89
1,720.41
$ c-
$ c.
23,365.27
16.43
587.81
1,884.32
4.93
73,974.37
1,646 16
0.03
1,719 50
16.46
2,265.56
98,881.55
101,293.11
THUNDER BAY SYSTEM
Reserve for Obsolescence and Contingencies— October 31, 1933
Balance brought forward October 31, 1932 $711,241 .06
Added during the year ending October 31, 1933:
Amount included in the costs of distribution of power within
rural power districts $869 . 29
Share of profits realized in respect of the sale of certain of the
Commission's investment securities 2,527 . 1 1
Interest at 4 % per annum on monthly balances at the credit of
the account 28,449 .64
31,846.04
$743,087.10
Deduct:
Commission's share of American exchange paid during the year
by the Province of Ontario on the transfer of funds to New
York to meet capital retirements 27,690 . 79
Balance carried forward October 31, 1933 $715,396.31
264
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
THUNDER BAY SYSTEM
T.B.— SINKING FUND
Statement showing Sinking Fund paid by each Municipality in the periods mentioned
hereunder as part of the cost of power delivered thereto, together with
its proportionate share of other sinking funds provided out
of other revenues of the system, and interest
allowed thereon to October 31, 1933
Municipality
Period of years ending
October 31, 1933
Amount
Fort William
Port Arthur
Township of Nipigon
Rural Power Districts*
Fort William R.P.D
Port Arthur R.P.D
7 years
7 "
7 "
2 years
2 "
$ c.
239,785.83
821,761.42
1,439.22
611.43
355.55
Total
1,063,953.45
*For townships included in rural power districts see "Cost of Power" and "Rural Operating'
statement preceding.
ACCOUNT WITH THE PROVINCIAL TREASURER— NIAGARA AND
Feb. 8, 1933 Cash returned to the Province in the year ending
June 19, 1933 October 31, 1933, to cover the difference between
Aug. 8, 1933 advances by the Province to the Commission
and the capital expenditures made out of such
advances by the Commission in the year ending
October 31, 1932
Feb. 8, 1933 Repayment to the Province of the investment —
according to book values — in the distribution
system in Cobourg (in the former Central Ontario
System) upon the sale of these properties to the
municipality
April 30, 1933 Paid on account of interest and exchange $5,274,086.46
Oct. 31, 1933 Cheque to cover balance of interest and exchange
for year ending October 31, 1933 5,326,005 .30
Oct. 31, 1933 Payment under debt retirement plan
Oct. 31, 1933 Balance carried down
$339,473.57
451,585.69
10,600,091.76
2,155,176.38
187,964,549.41
$201,510,876.81
1934 HYDRO-ELECTRIC POWER COMMISSION 263
THUNDER BAY SYSTEM
Reserve for Sinking Fund — October 31, 1933
Total provision for sinking fund to October 31, 1932 $887,461 .03
Provided in the year ending October 31, 1933:
By charges included in the cost of power delivered to munici-
palities and rural power districts $105,741 . 76
By charges included in the costs of distribution of power within
rural power districts 457 . 68
By charges against contracts with private companies which
purchased power 34,794 . 54
Interest at 4 % per annum on amounts standing at the credit of
the reserve accounts 35,498 . 44
176,492.42
Total ' $1,063,953.45
OTHER SYSTEMS—FOR THE YEAR ENDING OCTOBER 31, 1933
Oct. 31, 1932 Cash advances to date for the purposes of
Niagara and other Power Systems $204,488,631.44
Less repayments to that date under debt retire-
ment plan 14,853,440.35
$189,635,191 .09
Nov. 1, 19321
to \ Sundry cash advances 1,275,593 .96
Oct. 31, 1933 J
Oct. 31, 1933 Interest for year on all cash advances $10,522,687.93
Oct. 31, 1933 Commission's share of American exchange paid
during the year by the Province of Ontario
on the transfer of funds to New York to meet
interest and capital retirements 819,433 . 15
$11,342,121.08
Less — Interest credited by Province on repay-
ments made by Commission 742,029.32
10,600,091 . 76
$201,510,876.81
Nov. 1, 1933 Total cash advances $204,973,166. 14
Less — Payments made under debt retirement plan 17,008,616.73
$187,964,549.41
266 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
NORTHERN ONTARIO
Embracing the Nipissing, Wahnapitae, Abitibi-
Operating Account for the
Cost of Operation
Power purchased:
For Abitibi-Sudbury District to May 25, 1933, after which date power was
supplied from No. 1 unit of the Abitibi Canyon development $118,246.57
Costs of operation and maintenance, including the proportion of administrative
office expense chargeable to the operation of these properties 286,942 .24
Interest (including exchange thereon) on capital investment in generation and
transmission equipment 371,264.32
Provision for renewals of generation and transmission equipment 99,669.57
Provision for obsolescence and contingencies 31,316.85
Total costs of operation . ... $907,439.55
Operating surplus for year 20,258 . 19
$927,697.74
Provision — to extent of surplus available — for depreciation on Hunta-Copper Cliff
line for period prior to November 1, 1932 $20,258 . 19
Note. — Interest on expenditures on Abitibi Canyon development capitalized during construction.
NORTHERN ONTARIO PROPERTIES
Embracing the Nipissing, Wahnapitae, Abitibi-Sudbury and Patricia
(Ear Falls) Districts
Reserve for Renewals — October 31, 1933
Total provision for renewals to October 31, 1932 $339,105 .54
Deduct expenditures to October 31, 1932 51,379.73
Amount of reserves at October 31, 1932 $287,725 .81
Added during the year ending October 31, 1933 $119,927 . 76
Interest at 4 per cent, per annum on monthly balances at the credit of
the account 1 1 ,509 . 04
131,436.80
$419,162 61
Deduct expenditures during the year ending October 31, 1933 5,483 .51
Balance carried forward October 31, 1933 $413,679 . 10
1934 HYDRO-ELECTRIC POWER COMMISSION 267
PROPERTIES
Sudbury and Patricia (Ear Falls) Districts
Year Ending October 31, 1933
Revenue for Period
Power sold to private companies and customers $927,697 . 74
$927,697.74
Operating surplus for year brought down $20,258 . 19
NORTHERN ONTARIO PROPERTIES
Embracing the Nipissing, Wahnapitae, Abitibi-Sudbury and Patricia
(Ear Falls) Districts
Reserve for Obsolescence and Contingencies — October 31, 1933
Amount of reserves to October 31, 1932 $175,744 . 75
Added during the year ending October 31, 1933 $31,316.85
Share of profits realized in respect of the sale of certain of the Commis-
sion's investment securities 789 . 93
Interest at 4 per cent, per annum on monthly balances at the credit of
the account 7,029.79
39,136.57
$214,881.32
Deduct:
Contingencies met with during the year ending October 31, 1933 $648.00
Commission's share of American exchange paid during the year by
the Province of Ontario on the transfer of funds to New York
to meet capital retirements 2,629 . 86
3,277.86
Balance carried forward October 31, 1933 $211,603.46
268
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
NORTHERN ONTARIO
Nipissing Rural Power Districts —
Statement showing the costs of distribution of power within each Rural Power
and the amounts remaining to be credited to certain Districts or charged to
annual adjustment) of the actual costs
Total capital cost of each district,
Provincial Government grant
received and applied thereagainst,
and the balance representing the
investment by the Commission
District and municipalities
comprised therein
Cost of
power
Total
capital
cost
Govern-
ment
grant
Com-
mission's
investment
North Bay R.P.D.— West Ferris and Widdi-
field twps
$ c.
32,565.04
5,202.30
$ c.
15,911.74
2,601.15
$ c.
16,653.30
2,601.15
$ c.
3,993.41
Powassan R.P.D. — Himsworth South twp..
121.97
Totals
37,767.34
18,512.89
19,254.45
4,115.38
NORTHERN ONTARIO
Nipissing Rural Power Districts —
Statement showing the net Credit to each Municipality in respect of power supplied
Credited to each Municipality in respect of power supplied in the year
to each Municipality
Rural power district
Date
commenced
operating
Net credit at
October 31, 1932
Credit
North Bay R.P.D. — West Ferriss and Widdifield
twps
Powassan R.P.D. — Himsworth South twp
June, 19^7
Nov., 1931
$ c.
7,571.06
41.05
Totals
7,612.11
1934
HYDRO-ELECTRIC POWER COMMISSION
269
PROPERTIES
N I PISSING RURAL
Rural Operating
District, the revenues collected from (or charged to) customers within each District,
the Municipalities comprising certain other Districts upon ascertainment (by
in the year ending October 31, 1933
Distribution costs and fixed charges
Total
cost
Revenue
from
power and
light
customers
in each
district
Amounts remaining
to be credited to
Cost of
operation,
mainten-
ance and
adminis-
tration
Interest
(including
exchange)
Renewal
charges
Obsoles-
cence and
contin-
gencies
Sinking
fund
certain districts or
charged to the
municipalities com-
prising certain other
districts
Credited
Charged
$ c.
2,733.64
84.99
$ c.
799.00
127.80
$ c.
621.67
101.73
$ c.
310.83
50.87
$ c.
167.44
26.78
$ c.
8,625.99
514.14
$ c.
9,627.44
583.85
$ c.
1,001.45
69.71
$ c.
2,818.63
926.80
723.40
361.70
194.22
9,140.13
10,211.29
1,071.16
PROPERTIES
Credit or Charge
NI PISSING RURAL
to it to October 31, 1932, the interest added during the year; also the net amount
ending October 31, 1933, and the accumulated amount standing as a Credit
at October 31, 1933
Interest at 4 % per annum
added during the year
Net amount credited in respect
of power supplied in the year
ending October 31, 1933
Accumulated amount standing
as a credit on October 31,
1933
Credited
Credited
Credit
$ c.
302 . 84
1.64
$ c.
1,001.45
69.71
$ c.
8,875.35
112.40
304.48
1,071.16
8,987.75
270
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
NORTHERN ONTARIO
Nipissing Rural Power Districts — Reserve for Renewals
—October 31, 1933
Total provision for renewals to October 31, 1932 $2,958 .59
Added during the year ending October 31, 1933 723 .40
Interest at 4 per cent, per annum on monthly balances at the credit of the account 118.34
Balance carried forward October 31, 1933. $3,800.33
Nipissing Rural Power Districts— Sinking Fund
Statement showing Sinking Fund paid by each Rural Power District in the periods
mentioned hereunder, as part of the cost of power delivered thereto,
and interest allowed thereon to October 31, 1933
Rural power district
Period of years
ending
October 31, 1933
Amount
North Bay R.P.D. — West Ferris and Widdifield twps
Powassan R.P.D. — Himsworth S. twp
4 years
2 >;
$ c.
634.76
48.00
Total
682.76
NORTHERN ONTARIO
Manitoulin Island Rural Power
Statement showing the costs of distribution of power within Rural Power District,
amount remaining to be charged to the Municipalities comprising
costs in the year ending
Total capital cost of each district,
Provincial Government grant
received and applied thereagainst,
and the balance representing the
investment by the Commission
District and municipalities
comprised therein
Cost of
Total
capital
cost
Govern-
ment
grant
Com-
mission's
investment
power
purchased
Manitoulin R.P.D. — Gordon Allan, Billings
and Carnarvon twps., Town of Gore Bay
and Indian Reserve
$ c.
59,970.48
$ c.
27,344.69
$ c.
32,625.79
$ c.
3,281.25
934
HYDRO-ELECTRIC POWER COMMISSION
27
PROPERTIES NIPISSING RURAL
Nipissing Rural Power Districts — Reserve for Obsolescence and Contingencies
—October 31, 1933
Amount of reserves to October 31, 1932 . $919.50
Added during the year ending October 31, 1933 361 . 70
Interest at 4 per cent, per annum on monthly balances at the credit of the account 36.78
Balance carried forward October 31, 1933 $1,317.98
Nipissing Rural Power Districts — Reserve for Sinking Fund, October 31, 1933
Total provision for sinking fund to October 31, 1932 $469 . 75
Provided in the year ending October 31, 1933:
By charges included in the costs of distribution of power within rural
power districts $194 . 22
Interest at 4 % per annum on the amount standing at the credit of the
reserve accounts 18 . 79
213.01
$682.76
PROPERTIES
District — Rural Operating
MANITOULIN RURAL
the revenues collected from (or charged to) customers within the District, and the
this District upon ascertainment (by annual adjustment) of the actual
October 31, 1933
Distribution costs and fixed charges
Total
cost
Revenue
from
power and
light
customers
in each
district
Amounts remaining
to be credited to
Cost of
operation,
mainten-
ance and
adminis-
tration
Interest
(including
exchange)
Renewal
charges
Obsoles-
cence and
contin-
gencies
Sinking
fund
certain districts or
charged to the
municipalities com-
prising certain other
districts
Credited
Charged
$ c.
1,447.26
$ c.
1.434.09
$ c.
996.29
$ c.
476.90
$ c.
285.45
$ c.
7,921.24
$ c.
6,537.40
$ c.
$ c.
1,383.84
272 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
GUELPH
Operating Account for
Expenditure
Transportation expense $23,745 .09
Maintenance — way and structures 6,747 .34
Maintenance — equipment 15,566 .45
Electric power and motor fuel 9,469 .67
General opeiating and management expenses, including a proportion
of administrative and accounting expenses of the Commission
chargeable to the operation of the railway 10,577 .01
Insurance 3,700 .83
Taxes 353 . 89
$70,160.28
Interest 13,768.35
Provision for instalments payable to the City of Guelph on May 1,
1933, and November 1, 1933, under purchase agreement:
Interest for year. . $3,349.36
On account of principal 8,350 . 64
11,700.00
Provision for sinking fund 3, 159 . 00
$98,787.63
GUELPH RADIAL RAILWAY
Reserve for Renewals — October 31, 1933
Total provision for renewals to October 31, 1932 $55,793 .41
Deduct:
Expenditures to October 31, 1932 24,860.19
Balance brought forward October 31, 1932 ' . . . $30,933 . 22
Added during the year ending October 31, 1933:
Interest at 4 % on the monthly balances at the credit of the account 1,237.33
$32,170.55
Deduct:
Expenditures during the year ending October 31, 1933 697.57
Balance carried forward October 31, 1933 $31,472.98
1934 HYDRO-ELECTRIC POWER COMMISSION 273
RADIAL RAILWAY
the Year Ending October 31, 1933
Revenue
Operating revenue $57,455 .31
Net deficit for year payable by the City of Guelph 41,332 .32
$98,787.63
GUELPH RADIAL RAILWAY
Reserve for Sinking Fund— October 31, 1933
Total provision for sinking fund to October 31, 1932 $4,801.68
Provided in the year ending October 31, 1933 3,159.00
Interest at 4 % on the monthly balances at the credit of the account 192 . 07
Balance carried forward October\31, 1933 $8,152 .75
274 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
THE HAMILTON STREET
A Subsidiary of the Hydro-Electric
Balance Sheet —
Assets
Properties, road, equipment, motor buses, franchises, etc., as shown
in the books of the Company $4,777,945.79
Less — Reserves for renewal —
Of properties, road and equipment $695,341 . 72
Of motor buses (fully covered) 189,586.94
884,928.66
$3,893,017.13
Expenditures by Company in respect of T.H. & B. subway at James Street —
carried forward pending final allocation of total cost of subway by Dominion
Railway Board 20,932 . 78
Materials and supplies 56,652 . 25
Cash in bank $12,438.70
Cash in hands of conductors and other employees 10,940.00
23,378.70
Accounts receivable — Less reserve for doubtful accounts 5,687 .93
Taxes and insurance prepaid 6,699 . 08
$4,006,367.87
THE HAMILTON STREET
A Subsidiary of the Hydro -Electric
Statement of Revenue and Expenditure —
Expenditure
Transportation expenses $311,303 . 17
Maintenance — Way and structures 50,568 . 84
Maintenance — Equipment 100,968 .86
Power and motor fuel — including power purchased 177,362 . 25
General operating and management expenses, including a proportion of adminis-
trative and accounting expenses of the Commission chargeable to the operation
of the railway 49,945 . 13
Taxes 56,761 .03
Insurance — Fire, accident and liability 40,117.96
Total operating expenses $787,027 . 24
Net profit for year, before provision for renewal of road and equipment 27,307 .72
$814,334 96
1934 HYDRO-ELECTRIC POWER COMMISSION 275
RAILWAY COMPANY
Power Commission of Ontario
October 31, 1933
Liabilities
Issued— 64,100 shares of a par value of $50.00 each $3,205,000.00
Capital surplus — Created by advances to the Company by Dominion
Power & Transmission Company Limited, prior to 3 1st December,
1929 488,846.85
$3,693,846.85
Profit and loss account at October 31st, 1932 $21,929 59
Less charges thereagainst in the last fiscal year 3,968 .35
17,961.24
Hydro-Electric Power Commission of Ontario —
Cash advances 250,837 . 27
Accounts payable and accrued charges , 37,922.51
Reserve for outstanding tickets 5,800 . 00
Contingent liability —
Share of cost of T.H. & B. subway at James Street expected to be
found payable by Company upon final allocation of total
cost of subway by Dominion Railway Board.
$4,006,367.87
RAILWAY COMPANY
Power Commission of Ontario
For the Year ending October 31, 1933
Revenue
Passenger $799,074 . 63
Freight and express 2,961 . 80
Miscellaneous 12,298.53
Total Revenue $814,334.96
$814,334.96
Note:
Interest on Commission's advances to, and investment in capital stock of, the
Hamilton Street Railway Company $164,220 .43
in excess of profit for year (before provision for renewal of road and equip-
ment) from operation of the street railway 27,307 . 72
a balance of $136,912.71
has been charged to the contingency reserve of the Niagara system.
276 TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
APPROPRIATIONS, ADVANCES AND CAPITAL EXPENDITURES
For the Year Ending October 31, 1933
Appropriations made by the Legislature for the purposes of the Commission, Cash
Advances by the Province to the Commission on account of such appropriations,
and the Capital Expenditures made on each Undertaking and System
by the Commission out of such Cash Advances in the Year
Ending October 31, 1933
NIAGARA SYSTEM
Appropriations by Legislature:
For power developments, including Chats Falls $730,000.00
For transformer and distributing stations 550,000 .00
For transmission lines and rural distribution systems 600,000.00
For miscellaneous 350,000 . 00
$2,230,000.00
Cash advances to the Commission out of such appropria-
tions $1,294,785 . 00
Deduct: Amount returned to the Province on October
31, 1933 500,000.00
$794,785.00
Unexpended balance as at October 31, 1933, returnable to Province. 294,591.31
$500,193.69
Capital expenditure by the Commission:
On Chats Falls development $289,262 .38
On Ontario Power development „ 4,546 . 77
On steel-tower lines 7,680 . 73
On wood-pole lines 17,201 .56
On transformer stations 101,318.35
On Eastern transformer stations 168,532 .37
On Eastern right-of-way 113,078.46
On rural power districts 184,551 . 19
On local distribution systems 9,179.56
$895,351 .37
On Queenston-Chippawa development —
Receipts in excess of expenditures $35,294.98
On right-of-way —
Receipts in excess of expenditures 37,280. 19
On Eastern transmission lines —
Receipts in excess of expenditures 322,582.51
395,157.68
$500,193.69
GEORGIAN BAY SYSTEM
Appropriations by Legislature $405,000.00
Cash advances to the Commission out of such appropriations $89,042.00
Unexpended balance as at October 31, 1933, returnable to the Province 23,422 .53
Capital expenditure by the Commission:
On power developments $8, 743 . 56
On transformer stations 5,931 .46
On transmission lines 13,-505.96
On rural power districts 40,229.60
s $68,410.58
On local distribution systems —
Receipts in excess of expenditures 2,791 .11
$65,619.47
$65,619.47
1934 HYDRO-ELECTRIC POWER COMMISSION 277
EASTERN ONTARIO SYSTEM
Appropriations by Legislature $305,000 .00
standard
depreciation allocation aggregating $613,701.11; in the case of 36 utilities the
revenue was less than the total of operating expenses, interest and debt retirement
instalments by $95,258.10.
Statement "C" shows the installation of street lights in each municipality
together with the rates approved by this Commission, the revenue for 1933,
and the cost per capita in each municipality.
Statement "D" presents statistics relating to the supply of electrical
energy to consumers in Ontario municipalities served by the Commission. It
shows the revenue, kilowatt-hour consumption, number of consumers, average
monthly consumption, average monthly bill and the net average cost per
kilowatt-hour both for domestic and for commercial light service in each munici-
pality. For power service this statement shows the revenue, the number of
consumers and the average horsepower supplied by the municipal utility.* For
further reference to this informative statement, consult the special introduction
to it on page 406.
Statement "E" presents the cost per horsepower of the power provided
for and delivered to the municipalities by the Commission, and the local rates
to consumers in force in the respective municipalities, during the year 1933, for
domestic service, for commercial light service and for power service.
*The statistics include retail power only. Wholesale industrial power as supplied by the
Commission direct, is reported in Section IX.
Note: In 1933-34, the Ontario Municipal Electric Association requested information
respecting the remuneration paid certain members of the staff, and in this connection it was
stated that for this year the information would be placed in the Municipal section of the Annual
Report.
The Commission retains out of the salary of its employees an amount to provide for Pension
and Insurance. After such deduction the present (1933-1934) yearly remuneration to the following
members of the staff as requested is:— F. A. Gaby, $29,070.00; I. B. Lucas, $10,895.04; W. W.
Pope, $8,707.44; T. H. Hogg, $13,520.04; E. T. J. Brandon, $12,470.04; R. T. Jefferv, $10,895.04;
W. R. Robertson, $6,695.04; H. C. Don Carlos, $10,895.04; W. G. Pierdon, $10,895.04; A. E.
Davison, $5,532.72; W. P. Dobson, $6,170.04; B. O. Salter, $5,090.04; A. V. Trimble, $10,695.00;
A. V. White. $9,142.08. The present remuneration of the Chairman is $13,175.04 and Com-
missioners $7,975.08.
284
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
CONSOLIDATED
Year
1913
1914
1915
Number of municipalities included
45
69
99
Assets
Lands and buildings
Substation equipment
Distribution system — overhead
Distribution system — underground
Line transformers
Meters
Street lighting equipment — regular
Street lighting equipment — ornamental. .
Miscellaneous construction expenses. . . .
Steam or hydraulic plant
$ c.
626,707.34
1,090,875.69
2,690,834.74
644,514.24
615,546.20
840,606.64
900,614.80
62,765.34
866,551.89
1,401,175.28
341,277.00
$ c.
791,732.20
1,476,087.84
3,422,763.93
807,153.53
787,613.52
1,172,475.11
1,071,255.37
270,386.55
2,062,035.90
420,108.33
619,513.12
$ c.
873,838.18
1,582,062.56
4,234,626.05
928,420.77
981,754.70
1,418,165.08
1,309,628.49
197,644.82
1,701,182.66
461,651.60
Old plant
1,184,372.86
Total plant
10,081,469.16
450,887.97
12,901,125.40
422,350.12
14,873,347.77
Bank and cash balance
284,653.96
Securities and investments
Accounts receivable
Inventories
344,487.95
540,274.58
431,747.27
561,873.08
615,226.76
625,217.03
602,920.69
726,556.76
Sinking fund on local debentures
Equity in H-E-P.C. systems
868,983.78
Other assets
58,959.93
123,410.97
326,801.11
Total assets
11,907,826.86
15,249,203.36
17,683,264.07
Liabilities
Debenture balance
Accounts payable
Bank overdraft
8,711,308.37
1,553,711.45
160,919.16
42,412.81
10,678,078.36
1,682,150.29
228,622.50
113,838.66
11,831,811 .03
2,040,038.01
292,106.44
Other liabilities
37,388.31
Total liabilities
10,468,351.79
12,702,689.81
14,201,343.79
Reserves
For equity in H-E.P.C. systems
For depreciation
478,145.88
850,618.07
1,337,739.73
Other reserves. .
Total reserves
478,145.88
850,618.07
1,337 739.73
Surplus
Debentures paid
202,751.26
431,747.27
326,830.66
320,129.10
625,217.03
750,549.35
394,466.22
Local sinking fund
868,983.78
Operating surplus
880,730.55
Total surplus
961,329.19
1,695,895.48
2,144,180.55
Total liabilities, reserves and surplus. . .
11,907.826.86
15,249,203.36
17,683,264.07
Percentage of net debt to total assets. . .
88.0
88.3
80.3
Note. — In computing the percentage of net debt to total assets the sinking fund on local
debentures and equity in H-E.P.C. systems are excluded from assets, and total liabilities are
reduced by amount of local sinking fund.
934
HYDRO-ELECTRIC POWER COMMISSION
285
BALANCE SHEET
1916
1917
1918
1919
1920
1921
128
143
166
191
195
215
$ c.
1,335,936.33
1,934,626.12
4,832,353.27
1,095,709.62
1,179,132.07
1,711,299.49
1,251,057.13
306,388.95
2,059,263.42
864,500.01
759,748.66
$ c.
1,546,241.41
2,471,293.82
6,090,073.42
1,157,059.90
1,483,839.44
1,999,095.48
1,237,734.69
361,975.74
2,184,015.84
896,753.20
649,852.51
$ c.
1,859,888.69
2,820,488.70
6,627,237.39
1,216,288.59
1,772,691.35
2,238,143.70
1,200,625.65
531,502.61
2,395,096.50
214,575.75
1,476,413.00
$ c.
1,995,545.83
2,915,125.56
7,445,8z0.31
1,206,296.88
2,073,113.45
2,587,566.32
1,206,638.71
546,497.68
2,530,101.08
986,200.57
805,959.89
$ c
2,175,568.24
3,231,050.80
8,579,881 .49
1,313,369.29
2,560,581.59
3,053,135.20
1,269,006.98
557,678.13
2,697,636.12
757,194.47
864,298.39
$ c.
3,230,985.63
5,403,689.90
8,397,361.48
1,401,135.97
3,077,649.83
3,552,076.79
1,335,997.13
610,586.70
3,030,134.16
704,848.46
912,388.55
17,330,015.07
1,061,029.90
20,077,935.45
340,026.50
22,352,951.93
391,194.91
24,298,866.28
462,437.23
627,076.53
1,921,166.69
1,032,569.75
1,925,455.77
369,071.89
86,216.05
27,059,400.70
943,858.12
341,855.88
2,022,538.88
1,400,671.89
2,244,004.34
577,584.06
25,447.07
31,656,854.60
900,842.34
477,678.69
695,152.23
764,504.59
1,166,017 .73
1,285,097.33
1,261,398.36
1,337,578.96
1,124,018.44
972,996.96
1,663,298.05
2,155,788.62
1,504,596.28
2,541,718.35
795,570.51
342,215.87
125,240.05
444,787.63
78,929.84
21,358,935.39
24,427,276.65
26,949,247.92
30,722,860.19
34,615,360.94
40,111,979.23
15,058,641.57
969,187.75
178,413.26
491,874.90
15,593,773.61
1,537,669.11
886,177.94
429,104.20
17,209,217.70
1,007,727.79
576,816.49
350,013.21
18,133,462.44
1,420,926.66
403,235.57
670,271.90
19,268,072.04
1,840,137.54
514,671.99
642,293.65
21,619,220.99
1,887,567.93
989,099.98
938,368.84
16,698,117.48
18,446,724.86
19,143,775.19
20,627,896.57
22,265,175.22
25,434,257.74
373,871.89
3,750,162.28
577,584.06
4,788,645.03
800,249.05
1,843,804.68
2,463,723.83
3,133,550.17
5,491,858.93
1,843,804.68
2,463,723.83
3,133,550.17
4,124,034.17
5,366,229.09
6,292,107.98
549,778.59
1,165,785.94
1,101,448.70
694,797.90
1,340,615.38
1,481,414.68
920,076.56
1,662,602.69
2,089,243.31
1,328,657.68
1,754,020.37
2,888,251.40
1,440,156.52
2,246,474.47
3,297,325.64
1,860,079.53
2,541,718.35
3,983,815.63
2,817,013.23
3,516,827.96
4,671,922.56
5,970,929.45
6,983,956.63
8,385,613.51
21,358,935.39
24,427,276.65
26,949,247.92
30,722,860.19
34,615,360.94
40,111,979.23
78.4
75.5
71.0
67.9
65.4
64.7
286
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
CONSOLIDATED
Ykar
1922
1923
1924
Number of municipalities included
226
235
248
Assets
Lands and buildings
$ c.
3,334,522.68
5,046,857.98
11,165,330.24
1,598,053.02
3,618,684.73
4,033,689.52
1,419,016.05
666,084.50
3,261,495.74
565,158.54
7,997,947.87
$ c
4,488,054.93
6,015,919.75
13,135,581.76
1,959,120.41
4,211,655.89
4,548,933.73
1,061.473.85
708,431.22
3,681,274.88
566,619.86
8,051,496.28
$ c.
4,561 648 92
Substation equipment
6,800,238 00
Distribution system — overhead
Distribution system — underground
Line transformers
Meters
Street lighting equipment — regular
Street lighting equipment — ornamental..
Miscellaneous construction expenses. . . .
Steam or hydraulic plant
Old plant
14,182,190.33
2,873,446.13
4.456,669.02
5,149,629.71
1,134,491.77
728,298.08
4,168,262.21
4,196,803.45
5,587,420.31
Total plant
42,706,840.87
1,164,336.24
443,938.18
3,874,317.14
1,738,795.96
3,416,231.45
1,543,434.12
238,940.13
48,428,562.56
1,276,140.06
1,153,424.47
3,198,769.34
1,819,711.62
3,896,261.28
2,929,603.94
190,071.63
53,839,097.93
Bank and cash balance
1,748,912.34
Securities and investments
1,329,622.58
Accounts receivable
3,898,751.89
Inventories
1,745,628.16
Sinking fund on local debentures
Equity in H-E.P.C. systems
Other assets
4,520,723.06
5,420,567.58
250,292.77
Total assets ....
55,126,834.09
62,892,544.90
72,753,596.31
Liabilities
Debenture balance. .
30,454,186.12
3,699,292.52
456,706.69
586,203.02
33,056,501.29
3,708,781.76
680,714.59
1,517,828.47
38,005,162.50
Accounts payable
3,117,224.08
Bank overdraft
162,100.71
Other liabilities
1,780,564.27
Total liabilities
35,196,388.35
38,963,826.11
43,065,051.56
Reserves
For equity in H-E.P.C. systems
For depreciation
1,543,434.12
6,512,813.92
2,929,603.94
7,328,858.69
5,420,567.58
8,097,834.68
Other reserves
Total reserves
8,056,248.04
10,258,462.63
13,518,402.26
Surplus
Debentures paid
3,104,591.15
3,416,231.45
5,353,375.10
2,852,038.38
3,896,261.28
6,921,956.50
3,530,610.35
Local sinking fund
4,520,723.06
Operating surplus
8,118,809.08
Total surplus
11,874,197.70
13,670,256.16
16,170,142.49
Total liabilities, reserves and surplus. . .
55,126,834.09
62,892,544.90
72,753,596.31
Percentage of net debt to total assets. . .
63.3
62.6
61.4
1934
HYDRO-ELECTRIC POWER COMMISSION
287
BALANCE SHEET— Continued
1925
1926
1927
1928
1929
1930
247
251
252
256
260
267
$
c.
$
c.
$
c.
$
c.
$
(-.
$
c.
5,768,855
09
6,111,162
54
6,486,426
89
7,024,646.
76
7,469,451
46
7,936,974
31
8,543,166
55
9,505,501
77
15,088,905
14
16,866,186
21
18,102,792
13
19,485,056
28
16,837,535
57
18,654,240
54
16,689,462
41
17,688,050
68
18,108,016
82
19,220,326
48
3,388,837
09
3,689,569.95
3,278,382
58
3,559,288
16
4,823,369
60
4,932,189
05
5,079,754
23
5,538,605
24
5,985,521
37
6,549,674
64
7,312,742
17
7,953,090
23
5,533,483
92
5,963,162
51
6,346,660
59
6,839,802
90
7,405,478
91
7,840,948
07
1,256,916
53
1,309,608
30
1,399,314
06
1,486,646
24
1,594,183
25
1,780,785
67
893,186
48
1,103,660
23
1,184,035
82
1,203,706
65
1,458,349
64
1,520,891
01
4,485,110
96
3,456,777
71
3,360,671
09
3,394,626
92
3,483,487
78
3,996,747
77
568,912
49
628,909
57
607,320
00
619,880
93
489,097
57
139,587
28
4,549,142
46
4,655,422
59
5,095,555
90
5,032,089
26
5,093,378
75
5,322,690
14
56,904,902
27
60,616,620
95
65,522,255
85
70,264,599
35
75,340,348
08
80,129,286
29
1,700,145
30
2,136,290
79
3,014,832
48
1,342,367
07
858,733
68
2,722,250
12
1,095,662
92
1,400,316.43
1,696,237
66
1,837,140
51
2,001,088
81
1,909,439
11
3,417,558
86
3,508,817
87
3,715,770
72
4,097,446
13
4,683,201
97
4,481,006
92
1,711,504
13
1,397,667
83
1,412,729
41
1,220,186
10
1,365,033
58
1,242,994
51
5,202,451
70
5,599,675
01
6,398,909
77
7,071,273
69
7,753,613
88
8,396,255
47
7,551,588
70
8,046,868
53
10,143,205
66
12,326,097
56
14,754,865
40
17,346,372
44
137,280.05
33,151
81
31,942
45
153,275
04
152,260
86
173,030
05
77,721,093
93
82,739,409
22
91,935,884
Of)
9,8312,385
45
106,909,146
26
116,400.634
91
37,919,225
01
39,602,533
48
42,891,361
57
42,597,175
78
42,930,127
74
45,091,808
06
3,139,067
92
3,118,684
78
2,988,621
90
3,074,634
25
3,132,145
03
3,001,186
21
226,147
82
163,725
53
252,362
52
253,143
81
412,056
69
405,663
14
1,075,914
S3
1,087,795
08
1,154,810
24
1,258,610
23
1,621,378
17
1,642,771
59
42,360,355
58
43,972,738
87
47,287,156
23
47,183,564
07
48,095,707
63
50,141,429
00
7,551,588
70
8,046,868
53
10,143,205
66
12,326,097
56
14,754,865
40
17,346,372
44
8,699,437
68
9,360,322
27
10,319,889
05
11,140,795
68
11,911,154
49
12,885,387
51
1,157,147
20
947,970
23
1,002,916
69
1,117,257
63
1,437,371
26
1,574,655
74
17,408,173
58
18,355,161
03
21,466,011
40
24,584,150
87
28,103,391
15
31,806,415
69
4,440,138
34
5,493,879
S3
6,648,767
3S
7,928,907
61
9,194,253
59
10,728,279
.15
5,202,451
70
5,599,675
01
6,398,909
77
7,071,273
69
7,962,121
.20
8,396,255
.47
8,309,974
.73
9,317,954.48
10,135,039
.22
11,544,489
21
13,553,672
.69
15,328,255
.60
17,952,564
77
20,411,509
32
23,182,716
.37
26,544,670
51
30,710,047
.48
34,452,790
22
77,721,093
93
82,739,409
22
91,935,884
00
98,312,385
45
106,909,146
.26
116.400,634
.91
57.2
55.5
54.2
50.8
47.8
46.0
288
TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
CONSOLIDATED BALANCE SHEET— Concluded
Yeak
1931
1932
1933
Number of municipalities included
275
280
282
Assets
Lands and buildings
$ c.
8,407,664.48
21,013,956.74
19,918,355.76
5,361,627.24
8,649,875.07
8,106,202.88
2,205,613.18
1,456,742.91
3,827,132.05
458,374.05
7,146,437.96
$ c.
9,503,743.78
22,288,781.68
20,866,767.32
5,820,056.75
9,392,662.62
8,403,251.67
2,257,618.20
1,545,354.93
4,120.926.11
498,231.69
4,989,654.97
200,000.00
$ c
10,186,471.28
22,306,800.94
21,152,681.20
5,945,225.61
9 478 605 14
Substation equipment
Distribution system — overhead
Distribution system — underground
8,514,165.03
2,381,599.40
1,458,443.68
4,040,859.74
502,978.62
5,016,755.92
Street lighting equipment — regular
Street lighting equipment — ornamental..
Miscellaneous construction expenses. . . .
Steam or hydraulic plant
Old plant
Other plants not distributed .
200 000 00
Total plant
86,551,982.32
2,738,319.67
1,999,846.42
3,957,972.78
1,276,531.01
8,735,050.84
20,103.275.76
174,879.28
89,887,049.72
3,185,442.00
2,059,325.10
3,683,059.42
1,232,209.52
9,099,210.61
23,066,129.81
163,637.79
91,184,586.56
Bank and cash balance
1,696,489.24
Securities and investments
2,163,785.20
Accounts receivable
3,746,910.92
1,226,043.30
Sinking fund on local debentures
Equity in H-E.P.C. systems
Other assets
9,386,176.58
26,045,679.00
253,581.84
Total assets
125,537,858.08
132,376,063.97
135,703,252.64
Liabilities
Debenture balance
44,594,400.03
5,382,306.13
312,575.54
1,909,986.13
45,133,305.97
3,512,724.58
298,910.20
3,740,376.11
42,606,145.29
Accounts payable
3,320,485.45
Bank overdraft
206,398.00
Other liabilities
3,787,725.14
Total liabilities
52,199,267.83
52,685,316.86
49,920,753.88
Reserves
For equity in H-E.P.C. systems
For depreciation
20,103,275.76
13,748,049.68
1,693,129.83
23,066,129.81
14,902,177.02
1,902,308.64
26,045,679.00
16,075,959.28
Other reserves
2,048,081.84
Total reserves
35,544,455.27
39,870,615.47
44,169,720.12
Surplus
Debentures paid
13,150,040.37
8,735,050.84
15,909,043.77
15,244,778.28
9,099,210.61
15,476,142.75
17,651,367.71
Local sinking fund
9,386,176.58
Operating surplus
14,575,234.35
Total surplus
37,794,134.98
39,820,131.64
41,612,778.64
Total liabilities, reserves and surplus. . .
125,537,858.08
132,376,063.97
135,703,252.64
Percentage of net debt to total assets. . .
44.1
43.4
39.5
Note. — In computing the percentage of net debt to total assets the sinking fund on local
debentures and equity in H-E.P.C. systems are excluded from assets, and total liabilities are
reduced by the amount of local sinking fund.
1934
HYDRO-ELECTRIC POWER COMMISSION
289
CONSOLIDATED OPERATING REPORT
Year
1912
1913
1914
1915
Number of municipalities included
28
45
69
99
Earnings
Domestic service
$ c.
$ c.
572,154.38
525,438.16
905,378.17
$ c
789,130.81
673,803.92
1,214,829.31
$ c
944,271.08
Commercial light service . . .-
720,209.26
Commercial power service
1,501,797.78
Municipal power
Street lighting
560,925.56
698,409.71.
835,970.87
Rural service
Miscellaneous
53,543.24
57,482.41
68,046.29
Total earnings
1,617,674.00
2,617,439.51
3,433,656.16
4,070,295.28
Expenses
Power purchased
789,632.87
78,394.81
18,698.46
104,114.51
8,547.61
5,222.19
53,108.38
84,903.76
72,303.51
77,351.76
154,932.69
65,423.64
528,549.21
*
1,045,752.65
97,658.90
31,790.99
130,998.65
11,764.32
9,536.07
65,192.23
113,047.80
86,683.02
103,560.71
230,899.75
89,350.91
662,092.34
*
1,484,666.00
Substation operation
107,607.31
Substation maintenance
25,935.56
Distribution system, operation and
maintenance
154,409.71
Line transformer maintenance
11,508.92
Meter maintenance
12,899.14
Consumers' premises expenses
47,494.26
Street lighting, operation and main-
tenance
136,983.38
Promotion of business
74,402.55
Billing and collecting
131,541.27
General office, salaries and expenses
Undistributed expense
236,777 86
129,209.15
Interest
817,978.89
Sinking fund and principal pay-
ments on debentures
*
Total expenses
1,377,168.00
2,041,183.40
2,678,328.34
3,371,414.00
Surplus
240,506.00
124,992.47
576,256.11
262,675.24
755,327.82
357,883.31
698,881.28
Depreciation charge
414,506.99
Surplus less deprecation
115,513.53
313,580.87
397,444.51
284,374.29
*Debenture payments included in "Interest."
290
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
CONSOLIDATED
Year
1916
1917
1918
Number of municipalities included
128
143
166
Earnings
Domestic service
$ c.
1,172,878.96
812,130.78
1,921,152.31
$ c.
1,417,460.31
899,023.72
2,665,280.65
$ c.
1,632,272.12
968,399.42
3,417,248.37
Commercial light service
Commercial power service
Street lighting
930,057.48
967,495.10
902,875.55
Rural service
Miscellaneous
147,381.50
120,805.39
161,243.70
Total earnings
4,983,601.03
6,070,065.17
7,082.039.16
Expenses
Power purchased
1,959,446.83
153,761.08
46,131.53
154,247.17
14,528.17
24,218.48
52,602.01
145,471.50
154,508.58
306,709.35
97,333.97
*
2,573,879.37
203,091.20
42,129.04
169,326.24
25,328.95
44,461.55
61,765.14
157,857.73
188,083.84
349,932.05
102,938.80
*
2,807,769.33
238,257.34
60,805.92
223,347.81
30,488.83
63,155.56
65,149.59
196,157.18
208,660.76
421,680.15
117,474 07
Substation operation
Substation maintenance
Distribution system, operation and main-
tenance
Line transformer maintenance
Meter maintenance
Consumers' premises expenses
Street lighting, operation and mainten-
ance
Promotion of business
Billing and collecting
General office, salaries and expenses ....
Undistributed expense
*
Sinking fund and principal payments on
Total expenses
4,140,065.51
5,077,491.08
5,736,334 85
Surplus
843,535.52
486,141.80
992,574.09
607,296.29
1,345,704.31
Depreciation charge
718,162.30
Surplus less depreciation
357,393.72
385,277.80
627,542.01
*Debenture payments included in "Interest."
1934
HYDRO-ELECTRIC POWER COMMISSION
291
OPERATING REPORT— Continued
1919
1920
1921
1922
1923
1924
181
186
205
214
224
241
$ c.
1,991,632.31
1,175,143.56
3,443,107.13
$ c.
2,546,345.30
1,512,854.63
3,752,188.22
532,279.09
1,005,535.11
168,919.95
189,778.63
$ c
3,149,080.03
1,851,501.76
3,895,437.46
654,531.01
1,060,357.77
145,566.57
225,467.70
$ c.
3,786,608.23
2,158,306.34
4,383,912.97
973,263.38
1,160,446.81
105,877.09
187,689.39
$ c.
5,166,452.24
3,260,772.50
5,927,666.37
1,161,598.60
1,269,604.48
116,639.06
316,311.21
$ c.
5,993,231.07
3,566,227.22
6,222,865.88
1,352,966.47
988,900.95
1,356,668.97
75,100.24
228,270.65
231,663.58
7,827,054.60
9,707,900.93
10,981,942.30
12,756,104.21
17,219,044.46
18,798,723.43
3,284,490.68
217,638.89
81,853.63
286,310.76
42,509.12
78,726.64
84,301.24
215,963.86
74,789.22
236,504.75
452,131.22
190,690.09
1,285,571.51
*
4,216,667.87
285,407.35
102,050.81
344,551.57
46,323.09
123,701.18
116,283.52
236,930.79
78,294.85
295,942.88
559,695.29
256,400.33
1,431,807.16
*
4,876,650.31
314,838.35
104,798.01
487,918.33
65,088.46
116,722.97
134,854.92
297,481.52
101,804.46
321,685.71
656,268.11
308,874.42
998,611.47
532,183.96
6,636,853.37
315,443.70
100,763.67
519,252.16
52,932.26
107,806.88
143,388.88
297,363.86
129,932.63
338,153.50
605,852.50
385,895.03
1,074,657.44
635,469.90
8,699,026.67
474,442.13
133,815.53
636,477.41
75,920.10
139,104.81
218,682.02
299,579.08
184,371.00
444,306.92
937,463.47
359,206.91
1,615,205.16
990,907.14
9,669,789.40
430,056.09
202,050.04
648,700.62
82,936.50
141,231.23
237,316.20
269,973.30
202,060.74
490,273.30
889,907.66
494,078.50
1,779,991.26
1,122,798.87
6,531,481.61
8,094,056.69
9,317,781.00
11,343,765.78
15,208,508.35
16,661,163.71
1,295,572.99
814,219.37
1,613,844.24
902,028.75
1,664,161.30
1,044,434.85
1,412,338.43
715,814.24
2,010,536.11
916,782.75
2,137,559.72
973,649.62
481,353.62
711,815.49
619,726.45
696,524.19
1,093,753.36
1,163,910.10
292
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
CONSOLIDATED
Year
1925
1926
1927
Number of municipalities included
242
248
251
Earnings
Domestic service
$ c.
6,439,159.86
3,866,292.79
6,568,854.77
1,923,093.09
1,415,382.22
37,975.18
286,451.08
$ c.
7,372,602.62
4,187,899.19
6,789,217.54
1,922,512.34
1,457,686.21
37,810.73
471,134.15
$ c.
8,189,866.89
Commercial light service
4,626,815.51
Commercial power service
7,342,173.20
Municipal power
1,913,502.88
Street lighting
1,489,242.37
Rural service
13,765.72
Miscellaneous
581,913.04
Total earnings
20,537,208.99
22,238,862.78
24,157,279.61
Expenses
Power purchased
11,063,123.34
417,921.71
207,497.63
686,344.54
75,473.28
156,909.55
252,808.47
275,316.60
217,102.24
521,134.01
891,640.29
520,584.58
12,185,669.10
450,416.84
286,520.37
795,514.70
74,876.11
189,603.70
275,020.62
295,869.37
234,696.74
557,271.54
786,742.60
460,288.30
13,505,583.77
430,211 76
Substation operation
Substation maintenance.
275,148 86
Distribution system, operation and main-
ance
758,747.10
Line transformer maintenance
94,706.38
Meter maintenance
214,813.87
Consumers' premises expenses
285,352.68
Street lighting, operation and mainten-
ance
318,395.79
Promotion of business
220,687.60
Billing and collecting
605,627.58
General office, salaries and expenses . .
Undistributed expense
824,868.90
531,003.80
Truck operation and maintenance
Interest
1,889,810.95
1,294,027.29
1,985,233.73
1,347,511.92
2,063,698.00
Sinking fund and principal pavments on
debentures
1,505,626.31
Total expenses
18,469,694.48
19,925,235.64
21,634,472.40
Surplus
2,067,514.51
1,068,880.42
2,313,627.14
1,146,273.05
2,522,807.21
Depreciation charge
1,249,711.65
Surplus less depreciation
998,634.09
1,167,354.09
1,273,095.56
1934
HYDRO-ELECTRIC POWER COMMISSION
293
OPERATING REPORT— Concluded
1928
1929
1930
1931
1932
1933
255
259
267
275
280
282
$ c.
8,925,050.56
5,182,723.32
8,298,669.44
1,921,300.97
1,534,476.98
48,451.90*
465,791.92
$ c
9,873,681.57
5,697,766.06
9,376,158.74
2,086,444.24
1,598,262.43
51,590.54*
522,780.95
$ c.
10,542,903.89
5,961,383.23
9,340,653.28
2,111,482.38
1,674,528.03
28,954.60*
581,914.78
$ c.
10,972,952.10
6,230,475.89
9,456,224.97
1,967,118.54
1,746,855.24
29,446.38*
511,139.80
$ c.
11,447,307.85
6,243,794.01
9,356,693.88
1,859,585.35
1,783,972.46
11,069.27*
513,787.30
$ c.
11,429,101 13
6,013,025.96
9,080,522.07
1,826,872 07
1,779,582.48
*12,812.74
485,925.43
26,376,465.09
29,206,684.53
30,241,820.19
30,914,212.92
31,216,210.12
30,627,841.88
14,688,570.08
420,512.48
247,647.88
736,159.85
88,676.18
218,530.96
291,333.03
329,597.16
249,842.01
638,797.02
844,578.55
542,755.34
16,379,162.88
461,270.27
274,275.56
907,817.04
93,608.14
242,126.27
314,495.03
359,373.40
250,844.. 28
695,729.42
904,025.64
502,206.06
110,630.62
2,152,695.49
1,687,201.64
17,323,077.97
479,502.48
320,716.48
991,972.86
96,746.35
278,379.43
317,902.45
372,211.17
249,070.05
745,159.02
907,226.89
523,862.96
112,029.82
2,220,214.45
1,828,061.62
18,085,166.51
487,484.17
303,536.11
1,015,256.14
93,463.24
284,633.88
363,078.47
368,119.49
255,956.03
792,983.99
923,676.84
520,893.10
107,918.93
2,328,094.32
2,061,718.79
19,109,036.25
503,351.82
300,186.15
969,750.61
95,485.55
300,104.85
368,208.73
360,709.76
266,760.84
818,721.33
960,558.88
436,692.96
112,059.90
2,532,940.93
2,244,367.86
19,330,861.58
484,764.57
288,583.29
895,350.99
82,321.32
283,115.98
361,499.20
353,082.15
259,936.42
817,660.03
908,517.79
349,101.36
105,452.68
2,111,049.49
1,601,711.32
2,426,286.35
2,319,319.09
23,009,761.35
25,335,461.74
26,766,134.00
27,991,980.01
29,378,936.42
31,254,853.21
3,366,703.74
1,350,252.16
3,871,222.79
1,469,846.83
3,475,686.19
1,574,991.68
2,922,232.91
1,775,330.69
1,837,273.70
1,920,896.22
1,361,989.08
1,989,000.41
2,016,451.58
2,401,375.96
1,900,694.51
1,146,902.22
83,622.52
(loss)
627,011.33
(loss)
* Profits from the sale of merchandise. Rural service now given in "Rural Power Districts.'
Consult Section IX.
294
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Balance Sheets of Electrical Departments of
NIAGARA
SYSTEM
Municipality
Acton
1,895
Agincourt
P.V.
Ailsa
Craig
464
Alvinston
690
Amherst-
Population
burg
3,086
Assets
Lands and buildings
$ c.
1,545.45
1,847.39
23,482.38
$ c.
$ c.
$ c.
133.56
$ c.
Substation equipment
932 00
Distribution system — overhead. . .
Distribution system- — underground
Line transformers
8,481.56
8,174.03
14,008.12
33,614.83
11,302.83
10,472.15
1,880.04
3,686.18
2,479.55
767.19
1,946.95
2,571.67
404.09
3,024.48
2,972.37
1,090.62
15,917.83
Meters
15,219.85
Street light equipment, regular. . . .
Street light equipment, ornamental
Miscellaneous construction expense
Steam or hydraulic plant
812.44
5,598.72
2,620.49
104.85
492.36
791.52
1,600.27
Old plant .
3,481.50
773.85
Other plants not distributed
Total plant
56,632.23
3,137.53
1,500.00
592.60
818.04
15,519.33
2,511.49
1,000.00
1,139.69
2.04
13,589.10
3,205.11
5,000.00
39.15
22,794.52
282.09
2,000.00
456.09
73,695.94
7,440.26
Bank and cash balance
Securities and investments
Accounts receivable
1,898.30
2,437.20
Inventories
Sinking fund on local debentures. .
Equity in H-E.P.C. systems
Other assets
34,576.27
589.02
5,182.99
9,541.72
9,622.20
27,567.04
3,140.64
Total assets
97,845.69
25,355.54
31,375.08
35,154.90
3,814.05
116,179.38
Deficit
Total
97,845.69
25,355.54
31,375.08
38,968.95
116,179.38
Liabilities
Debenture balance
3,433.73
583.80
12,450.39
916.90
25,176.10
Accounts payable
13.13
200.65
Bank overdraft
Other liabilities
542.09
92.00
7,144.27
Total liabilities
555.22
4,017.53
292.65
13,367.29
32,320.37
Reserves
For equity in H-E.P.C. systems. . .
For depreciation
34,576.27
9,654.09
5,182.99
1,530.63
9,541.72
5,174.27
9,622.20
4,900.61
27,567.04
14,021.84
Other reserves
Total reserves
44,230.36
6,713.62
14,715.99
14,522.81
41,588.88
Surplus
Debentures paid
14,500.00
4,638.92
6,883.38
11,078.85
6,877.50
Local sinking fund
Operating surplus
38,560.11
9,985.47
9,483.06
35,392.63
Total surplus
53,060.11
14,624.39
16,366.44
11,078.85
42,270.13
Total liabilities, reserves and surplus
97,845.69
25,355.54
31,375.08
38,968.95
116,179.38
Percentage of net debt to total assets
0.8
19.9
1.3
52.4
32.2
1934
HYDRO-ELECTRIC POWER COMMISSION
293
'A v
Hydro Municipalities as at December 31, 1933
Ancaster
Twp.
Arkona
416
Aylmer
1,989
Ayr
768
Baden
P.V.
Beachville
P.V.
Belle
River
746
Blenheim
1,690
$ c.
$ c.
$ c.
9,019.23
$ c.
125.00
$ c.
660 . 64
$ c.
176.13
$ c.
$ c.
909.64
15,858.22
9,559.67
20,733.69
12,440.57
7,474.60
13,922.72
16,266.23
25,681.74
10,236.49
4,202.68
1,269.78
1,976.44
1,549.36
671.60
10,356.91
9,591.53
1,723.79
3,850.56
3,580.79
628.42
4,048.22
2,872.74
447.45
3,550.21
3,142.06
423.23
3,651.15
3,683.98
924.29
8,123.02
9,116.00
3,367.96
1,482.97
324 93
225.47
1,130.33
941.79
602.04
1,043.78
1,128.43
1,030.30
6,719.17
4,002.53
31,892.10
15,012.84
88.03
59,274.65
1,314.13
12,000.00
1,365.89
60.62
25,569.66
57.93
15,503.65
3,831.00
21,816.39
522.43
4,000.00
722.31
25,569.43
3,631.25
3,000.00
744.16
49,809.76
4,343.02
1,761.46
176.18
1,196.70
692.65
30.34
8,321.47
2,948.25
54.54
22,779.10
8,153.15
19,259.17
23,913.36
5,164.20
21,191.34
41,975.03
18,279.84
1,561.01
96,794.39
34,977.44
38,593.82
50,974.49
38,109.04
76,067.11
41,975.03
19,840.85
96,794.39
34,977.44
38,593.82
50,974.49
38,109.04
76,067.11
7,921.48
425.70
9,736.09
2,410.16
20,208.85
99.83
6,948.52
2,102.21
161.80
2,286.51
5,454.34
158.04
8,527.23
1,789.88
1,659.51
145.32
108.00
86.00
220.00
10,152.01
12,146.25
20,416.68
6,948.52
2,264.01
2,286.51
5,698.38
10,537.11
8,321.47
6.199.21
2,948.25
1,369.61
22,779.10
9,529.63
300.00
8,153.15
3,696.68
19,259.17
1,759.67
23,913.36
4,793.88
5,164.20
4,685.02
5,000.00
21,191.34
10,739.62
14,520.68
4,317.86
32,608.73
11,849.83
21,018.84
28,707.24
14,849.22
31,930.96
2,868.10
3,376.74
18,493.07
10,554.86
2,897.79
3,066.49
3,045.66
5,472.77
14.434.24
25,275.91
5,624.23
12,413.18
16,914.25
14,515.78
28,126.27
17,302.34
3,376.74
43,768.98
16,179.09
15,310.97
19,980.74
17,561.44
33,599.04
41,975.03
19,840.85
96,794.39
34,977.44
38,593.82
50,974.49
38,109.04
76,067.11
30.1
79.2
27.5
25.9
11.7
8.4
17.3
16.9
296
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Balance Sheets of Electrical Departments of
NIAGARA
SYSTEM— Continued
Municipality
Blyth
602
Bolton
593
Bothwell
646
Brampton
5,413
Brantford
Population
30,724
Assets
Lands and buildings
$ c.
$ c.
$ c.
$ c.
5,081.32
24,742.53
50,295.58
$ c.
85,595.31
Substation equipment
162,884.45
Distribution system — overhead. . .
Distribution system — underground
Line transformers
11,261.08
9,931.57
6,027.41
229,785.83
6,000.00
2,441.35
1,945.31
1,284.19
4,296.34
2,958.86
856.19
2,575.37
2,819.97
4,634.70
28,005.83
26,131.27
2,645.94
112,926.91
Meters
115,872.40
Street light equipment, regular. . . .
Street light equipment, ornamental
Miscellaneous construction expense
Steam or hydraulic plant
24,010.22
41,476.69
284.97
1,050.06
550.01
18,405.35
30,529.82
Old plant .
2,332.68
1,554.60
Other plants not distributed
200,000.00
Total plant
19,549.58
1,173.22
20,647.62
895.96
16,607.46
2,475.99
11,000.00
82.04
155,307.82
2,400.28
5,648.78
1,100.49
223.66
1,009,081.63
Bank and cash balance
Securities and investments
Accounts receivable
1,009.53
704.36
22.41
23,077.31
Inventories
11,344.36
Sinking fund on local debentures. .
90,906.83
Equity in H-E.P.C. systems
Other assets
4,935.50
10,636.75
11,113.15
93,084.35
473,680.24
47,506.37
Total assets
Deficit
26,667.83
32,907.10
41,278.64
257,765.38
1,655,596.74
Total
26,667.83
32,907.10
41,278.64
257,765.38
1,655,596.74
Liabilities
Debenture balance
Accounts payable
9,006.10
100.31
6,013.66
52.00
3,045.38
226.32
12,794.35
1,842.74
263,000.00
6,587.33
Bank overdraft
11,241.61
Other liabilities
50.00
1,161.22
166,542.06
Total liabilities
9,156.41
6,065.66
4,432.92
14,637.09
447,371.00
Reserves
For equity in H-E.P.C. systems. . .
For depreciation
4,935.50
2,774.77
10,636.75
4,997.25
11,113.15
5,755.07
93,084.35
42,919.03
100.00
473,680.24
203,667.20
Other reserves
86,000.00
Total reserves
7,710.27
15,634.00
16,868.22
136,103.38
763,347.44
Surplus
Debentures paid
7,262.93
6,486.34
2,488.81
56,256.29
267,000.00
Local sinking fund
90,906.83
Operating surplus
2,538.22
4,721.10
17,488.69
50,768.62
86,971.47
Total surplus
9,801.15
11,207.44
19,977.50
107,024.91
444,878.30
Total liabilities, reserves and surplus
26,667.83
32,907.10
41,278.64
257,765.38
1,655,596.74
Percentage of net debt to total assets
42.2
27.2
11.4
8.9
33.5
934
HYDRO-ELECTRIC POWER COMMISSION
297
"A"— Continued
Hydro Municipalities as at December 31, 1933
Brantford
Twp.
Bridgeport
P.V.
Brigden
P.V.
Brussels
770
Burford
P.V.
Burgess-
ville
P.V.
Caledonia
1,400
Campbell-
ville
P.V.
$ c.
$ c.
$ c.
101.03
$ c.
$ c.
202.00
$ c.
$ c.
$ c.
1,192 71
52,268.73
9,516.09
7,090.80
13,562.61
9,240.38
3,490.03
17,022.28
2,978.42
16,784.09
11,884.39
4,338.80
3,833.06
2,217.15
1,602.69
2,037.61
2,238.85
464.90
2,395.35
3,810.08
1,574.74
2,933.19
3,374.95
425.14
1,390.44
966.40
261.02
6,432.74
6,232.50
1,582.94
718.23
567.30
258.56
2,922.09
563.56
858.11
1,572.29
717.31
457.22
692.59
45.82
1,381.00
2,827.50
89,390.81
6,741.22
17,732.55
300.27
14,172.30
475.66
25,742.57
3,959.91
16,892.97
1,884.70
4,000.00
571.36
6,565.11
560.08
31,963.05
1,638.23
2,000.00
20.65
4,568.33
525.63
1,000.00
405 . 19
241.36
473.04
838.83
24.48
107.09
268.67
3,326.87
15,720.56
2,607.10
7,049.89
6,968.52
7,656.25
25.00
3,190.64
12,346.64
860.46
115,584 65
20,881.28
22,170.89
37,534.31
31,030.28
10,422.92
47,968.57
7,223.09
115,584.65
20,881.28
22,170.89
37,534.31
31,030.28
10,422.92
47,968.57
7,223.09
23,408.79
3,272.61
11,914.39
698.27
902.89
13,245.52
1,847.51
382.11
4.60
560.39
220.22
1,780.41
701.06
3,593.44
33.14
1,443.25
40.00
25.00
28,124.65
12,652.66
902.89
15,093.03
411.71
780.61
2,481.47
3,626.58
15,720 56
17,690.56
2,607.10
4,458.60
7,049.89
3,072.84
6,968.52
4,010.41
7,656.25
4,050.20
3,190.64
2,229.03
85.41
12,346.64
3,949.40
860.46
676.54
33,411.12
7,065.70
10,122.73
10,978.93
11,706.45
5,505.08
16,296.04
1,537.00
33,716.87
3,326.87
453.64
7,097.11
7,754.48
8,617.89
2,939.61
2,843.59
1,854.33
17,005.14
709.28
4,048.16
3,707.87
10,294.23
1,197.62
26,347.47
205.18
54,048.88
1,162.92
11,145.27
11,462.35
18,912.12
4,137.23
29,191.06
2,059.51
115,584.65
20,881.28
22,170.89
37,534.31
31,030.28
10,422.92
47,968.57
7,223.09
25.6
69.2
5.9
49.4
1.7
10.8
6.9
57.0
298
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Balance Sheets of Electrical Departments of
NIAGARA
SYSTEM— Continued
Municipality
Cayuga
705
Chatham
16,223
Chippawa
1,073
Clifford
454
Clinton
Population
1,842
Assets
Lands and buildings
$ c.
$ c.
46,055.45
116,587.41
161,316.09
79,554.42
86,934.79
67,774.93
18,777.35
35,426.10
33,016.43
$ c.
631.50
$ c.
$ c.
8,760.82
Substation equipment
7,544.43
Distribution system — overhead . . .
Distribution system — underground
Line transformers
14,080.88
19,123.86
7,451.37
22,257.65
3,162.29
2,704.35
942.83
6,107.56
4,702.80
1,877.81
1,161.99
2,195.08
687.42
7,787.65
Meters
9,334.88
Street light equipment, regular. . . .
Street light equipment, ornamental
Miscellaneous construction expense
Steam or hydraulic plant
1,297.67
474.44
1,139.19
37.44
3,846.29
Old plant
42,752.31
10,658.09
Other plants not distributed
Total plant
21,364.79
2,141.86
688,195.28
17,934.82
33,582.72
421.83
11,533.30
400.44
71,487.48
Bank and cash balance
1,991.97
Securities and investments
3,000.00
Accounts receivable
Inventories
389.17
131.34
18,793.38
3,703.83
253.38
131.53
20.40
1,276.61
2,230.83
Sinking fund on local debentures. .
32,589.70
Equity in H-E.P.C. systems
Other assets ....
4,608.67
222,270.09
3,604.51
9,683.44
194.56
3,400.81
26,385.91
Total assets
28,635.83
954,501.91
44,135.93
15,486.48
138,962.50
Deficit
Total
28,635.83
954,501.91
44,135.93
15,486.48
138,962.50
Liabilities
Debenture balance
Accounts payable
13,543.57
851.67
245,238.03
23,289.92
6,422.39
32.01
6,756.82
373.14
44,500.00
495.93
Bank overdraft ....
Other liabilities
35.00
39,030.61
190.00
175.81
Total liabilities
14,430.24
307,558.56
6,644.40
7,129.96
45,171.74
Reserves
For equity in H-E.P.C. systems. . .
For depreciation
4,608.67
3,035.70
222,270.09
108,582.98
4,974.96
9,683.44
6,469.01
3,400.81
1,657.34
26,385.91
20,000.45
Other reserves.
670.39
Total reserves
7,644.37
335,828.03
16,152.45
5,058.15
47,056.75
Debentures paid
6,456.43
124,761.97
6,927.61
1,243.18
Local sinking fund
32,589.70
Operating surplus
104.79
186,353.35
14,411.47
2,055.19
14,144.31
Total surplus
6,561.22
311,115.32
21,339.08
3,298.37
46,734.01
Total liabilities, reserves and surplus
28,635.83
954,501.91
44,135.93
15,486.48
138,962.50
Percentage of net debt to total assets
60.1
36.7
19.2
59.0
15.7
1934
HYDRO-ELECTRIC POWER COMMISSION
299
"A"— Continued
Hydro Municipalities as at December 31, 1933
Comber
P.V.
Cottam
P.V.
Courtright
348
Dashwood
P.V.
Delaware
P.V.
Dorchester
P.V.
Drayton
559
Dresden
1,488
$ c.
$ c.
$ c.
$ c.
$ c.
$ c.
$ c.
$ c.
523.00
7,231.00
9,112.46
6,515.06
3,402.64
3,764.27
8,048.67
9,333.37
18,494.68
3,422.04
2.459.87
384.93
1,538.31
1,778.79
359.43
1,225.40
880.37
425.08
1,600.44
1,378.45
353.42
914.44
962.46
148.08
3,286.91
2,411.76
496 . 74
3,328.48
3,254.24
673.50
7,524.07
5,912.96
1,127.48
977.24
220.64
558.67
291.87
203.81
328.41
401.02
553.99
4,815.01
14,475.08
3,261.56
13,009.63
3,366.01
9,604.58
686.28
7,026.82
1,351.20
1,500.00
6.70
5,993.06
1,026.21
2,500.00
309.09
14,572.49
2,101.25
2,000.00
67.93
16,990.61
484.02
5,000.00
109.57
38,951.19
1,024.08
2,000.00
291.61
226.38
25.43
1,610.34
565.40
11,265.98
1,912.56
3,068.73
4,929.81
1,607.07
3,991.12
6,777.75
17,862.77
120.00
29,294 ?3
18,514.58
13,385.02
14,814.53
11,435.43
22,732.79
29,361.95
62,133.78
29.294.23
18,514.58
13,385.02
14,814.53
11,435.43
22,732.79
29,361.95
62,133.78
1,633 6?
6,866.34
3,508.45
251.67
2,131.19
89.19
2,161.11
35.44
2,479.56
234.40
6,415.08
1,051.56
726.04
1,083.75
19.85
80.00
15.00
120.00
1.653.47
6,946.34
3,760.12
2,220.38
2,196.55
2,728.96
7,466.64
1,929.79
11.26S 98
4,535.27
1,912.56
2,422.63
3,068.73
1,103.15
4,929.81
1,917.52
1,607.07
869.58
3,991.12
1,585.97
6,777.75
5,133.06
17,862.77
4,918.02
225.00
15,801 75
4,335.19
4,171.88
6,847.33
2,476.65
5,577.09
11,910.81
23,005.79
6,066.38
2,133.88
4,629.90
1,268.81
1,838.89
1,820.44
3,084.92
15,512.21
5,773.13
5,099.17
823.12
4,478.01
4,923.34
12,606.30
6,899.58
21,685.99
11,839.51
7,233.05
5,453.02
5,746.82
6,762.23
14,426.74
9,984.50
37,198.20
29.294.23
18,514.58
13,385.02
14,814.53
11,435.43
22,732.79
29,361.95
62,133.78
9.2
41.8
36.4
22.4
22.3
14.5
33.1
4.1
300
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Balance Sheets of Electrical Departments of
NIAGARA
SYSTEM— Continued
Municipality
Drumbo
P.V.
Dublin
P.V.
Dundas
5,138
Dunnville
3,615
Dutton
Population
761
Assets
Lands and buildings
$ c.
$ c.
$ c.
12,111.11
13,396.22
50,052.10
$ c.
3,356 09
27,302.17
36,699.01
$ c.
Substation equipment . .
Distribution system — overhead . . .
Distribution system — underground
Line transformers. .
4,552.59
5,787.61
9,086.84
1,537.50
1,863.92
262.27
897.65
874.11
544.86
19,610.94
19,427.63
10,834.15
1,154.52
8,158.01
18,110.09
15,836.44
8,012.37
3,425.25
Meters
3,297.10
Street light equipment, regular. . . .
Street light equipment, ornamental
Miscellaneous construction expense
Steam or hydraulic plant
626.14
257.95
787.06
5,788.34
338.12
Old plant
1,867.38
10,717.62
Other plants not distributed
Total plant
8,474.23
2,878.65
8,891.29
269.38
136,612.06
11,192.92
1,500.00
4,375.02
439.24
125,822.13
35.00
10,000.00
7,493.12
886.01
16,773.45
Securities and investments
6,000.00
Accounts receivable
Inventories
294.88
54.53
229.23
430.27
22.82
Sinking fund on local debentures
Equity in H-E.P.C. systems
Other assets
3,658.36
3,357.12
81,992.63
2,084.98
32,056.77
11,117.92
120.17
Total assets
15,360.65
12,747.02
671.75
238,196.85
176,293.03
34,464.63
Deficit
Total
15,360.65
13,418.77
238,196.85
176,293.03
34,464.63
Liabilities
Debenture balance
2,431.53
61.91
1,345.99
858.79
25,859.07
1,743.12
49,929.04
8,571.83
2,394.44
1,225.35
4,758.84
Accounts payable
Bank overdraft ....
87.61
Other liabilities. .
3,086.83
47.36
Total liabilities
2,493.44
2,204.78
30,689.02
62,120.66
4,893.81
Reserves
For equity in H-E.P.C. systems . . .
For depreciation
3,658.36
2,933.41
3,357.12
3,002.86
81,992.63
41,922.00
350.52
32,056.77
24,741.85
11,117.92
5,650.56
Other reserves
Total reserves
6,591.77
6,359.98
124,265.15
56,798.62
16,768.48
Surplus
Debentures paid
2,068.47
4,854.01
27,140.93
25,570.96
3,648.65
Operating surplus
4,206.97
56,101.75
31,802.79
9,153.69
Total surplus
6,275.44
4,854.01
83,242.68
57,373.75
12,802.34
Total liabilities, reserves and surplus
15,360.65
13,418.77
238,196.85
176,293.03
34,464.63
Percentage of net debt to total assets
21.3
23.4
18.9
43.0
20 9
1934
HYDRO-ELECTRIC POWER COMMISSION
301
"A"— Continued
Hydro Municipalities as at December 31, 1933
East
Windsor
14,333
East York
Twp.
Elmira
2,642
Elora
1,144
Embro
455
Erieau
264
Erie
Beach
23
Essex
1,888
$ c.
$ c
16,946.49
8,514.27
281,256.98
$ c.
7,119.73
$ c
1,524.54
$ c.
$ c.
$ c.
$ c.
174,118.92
34,855.36
17.136.3C
9,588.07
9,286.94
1,889.54
35,810.48
442 55
74,978.65
60,661.87
75,986.83
140,084.77
20,605.46
15,509.18
12,767.67
1,380.05
7,301.95
5,803.86
1,235.43
3,039.64
2,072.23
535 . 73
1,600.23
2,300.97
246.10
613.17
732.78
15,011.34
10,630.12
1 548 10
89,295.42
3,439.78
15,185.88
3,817.89
1,339.05
69.45
379.90
375.03
2,583.63
2,168.08
1,425.47
429.25
402,494.64
83,957.95
558,580.68
9,129.20
2,812.91
23,978.79
6,841.18
77,617.96
402.84
35,766.60
56.17
7,000.00
574 16
619.32
15,734.37
1,117.19
1,000.00
468.29
13,814.14
3,610.52
377.32
66,026.22
6,822 20
5,000.00
3,250.40
13,939.00
350.46
413.81
307.31
125,360.56
116,767.89
46,936.38
22,693.58
6,527.33
2,938.52
747.87
15,657.28
625,752.15
718,110.65
125,307.64
66,709.83
24,847.18
17,166.47
5,043.02
96,756.10
625,752.15
718,110.65
125,307.64
66,709.83
24,847.18
17,166.47
5,043.02
96,756.10
98,715/1
27,803.76
260,603.69
52,687.72
138.46
14,270 65
24,587.85
3,021.39
3,749.15
518.81
156.87
35.00
3,215.44
135.95
4,540.17
1,124.94
62.35
15.00
2,547.11
18.33
19,003.56
1,186.17
89,295.42
678.65
565 13
215,814.89
327,700.52
28,287.89
4,459.83
3,351.39
5,742.46
2,565.44
20,754.86
125,360.56
46,069.95
430 . 24
116,767.89
54,274.59
1,672.50
46,936.38
15,623.42
22,693.58
11,246.10
6,527.33
4,660.64
2,938.52
1,806.50
747.87
368.36
15,657.28
11,061.83
950 00
171,860.75
33,939.68
4,745.02
27,669.11
50,284.29
96,464.09
12,580.65
9,250.85
4,284.56
2,342.96
752.89
3,496.44
187,792.22
121,231.06
21,879.30
19,059.47
6,023.26
4,336.03
608.46
44,835.69
238,076.51
217,695.15
34,459.95
28,310.32
10,307.82
6,678.99
1,361.35
48,332.13
625,752.15
718,110.65
125,307.64
66,709.83
24,847.18
17,166.47
5,043.02
96,756.10
30.7
54.5
36.0
10.1
18.3
40.3
59.7
25.5
302
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Balance Sheets of Electrical Departments of
NIAGARA
SYSTEM— Continued
Municipality
Etobicoke
Twp.
Exeter
1,622
Fergus
2,559
Fonthill
862
1,465
Assets
Lands and buildings
$ c.
26,109.75
$ c.
3,281.59
$ c.
$ c.
$ c.
6,447.40
Substation equipment
Distribution system — overhead . . .
Distribution system — underground
264,591.04
26,558.89
33,257.25
11,172.41
19,850.09
Line transformers
65,033.98
51,454.97
11,937.62
2,689.44
5,055.18
10,205.65
8,081.77
953.11
15,885.95
11,763.08
2,163.24
4,877.07
4,331.41
1,031.00
9,608.76
9,289 58
Meters
Street light equipment, regular. . . .
Street light equipment, ornamental
Miscellaneous construction expense
Steam or hydraulic plant
2,369.94
2,219.08
1,145.49
3,872.65
868.54
Old plant
2,546.59
11,042 87
Other plants not distributed
Total plant
426,871.98
51,300.09
6,274.48
3,000.00
2,525.10
2,034.19
66,761.60
1,032.62
25,284.54
59,477.18
4,166 54
Bank and cash balance
Securities and investments
7,500.00
21,905.49
5,431.65
1,149.81
108.80
605.01
3,161.98
1,714.49
Sinking fund on local debentures. .
Equity in H-E.P.C. systems
Other assets
92,232.23
4,782.46
23,307.91
28,771.67
2,800.14
219.24
16,729.43
Total assets
551,223.81
88,441.77
97,824.50
28,908.93
92,749.62
Deficit
Total
551,223.81
88,441.77
97,824.50
28,908.93
92,749.62
Liabilities
Debenture balance
185,435.62
28,000.00
9,674.35
7,471.90
8,211.16
191.98
18,458.35
1,893.70
16,901.54
10,654.92
Accounts payable
Bank overdraft
1,049.04
210.62
Other liabilities
104.25
10.00
26.06
Total liabilities
230,581.87
8,507.39
20,362.05
18,161.20
10,680.98
Reserves
For equity in H-E.P.C. systems. . .
For depreciation
92,232.23
61,087.59
760.79
23,307.91
9,738.21
85.90
28,771.67
7,874.37
2,800.14
1,677.44
16,729.43
11,921.44
Other reserves
50.00
Total reserves
154,080.61
33,132.02
36,646.04
4,477.58
28,700.87
Surplus
Debentures paid
80,259.78
11,788.89
23,541.65
5,598.46
23,745.08
Local sinking fund
Operating surplus
86,301.55
35,013.47
17,274.76
671.69
29,622.69
Total surplus
166,561.33
46,802.36
40,816.41
6,270.15
53,367.77
Total liabilities, reserves and surplus
551,223.81
88,441.77
97,824.50
28,908.93
92,749.62
Percentage of net debt to total assets
48.9
13.1
29.5
69.5
14.1
1934
HYDRO-ELECTRIC POWER COMMISSION
303
"A"— Continued
Hydro Municipalities as at December 31, 1933
Gait
14,036
George-
town
2,187
Glencoe
800
Goderich
4,366
Granton
P.V.
Guelph
20,754
Hagers-
ville
1,370
Hamilton
154,701
$ c.
200,400 85
$ c.
$ c.
$ c.
12,957.48
34,402.48
66,031.41
$ c.
$ c.
13,380.18
154,033.43
173,856.72
$ c.
864.37
$ c.
929,378.58
113,678.71
4,320.71
1,752,301.59
230,512.67
31,167.43
20,906.98
20,216.91
1,207,106 47
854,684.64
117,283.95
70,247.62
72,290.44
18,111.46
13,451.90
1,364.67
6,311.20
4,202.13
1,714.63
20,309.85
17,907.69
4,825.17
1,533.55
1,486.86
163.37
85,064.07
90,097.57
42,207.45
9,850.72
8,533.70
1,040.67
902,219.08
625,551.46
277,329.74
25,070.72
2,411.30
3,383.07
5,883.56
113.08
14,210.70
1,040.63
201,750.22
2,209.80
14,622.15
104,252.86
829,484.96
68,716.56
1,183.55
7,986.67
1,691.33
127.49
36,518.01
2,550.56
176,939.79
2,922.44
7,617.57
2,260.04
2,000.00
352.86
572,850.12
7,771.94
41,547.00
9,321.97
12,000.00
128.48
33.00
6,854,574.64
118,868.31
54,185.97
12,370.61
109 461 97
1,351.21
4,021.17
1,196.78
15,979.43
23,315.15
44,819.73
368,952.35
421,735.60
158,083.35
648,954.49
313,276.52
1,995.45
55,732.50
1,500.18
10,750.22
70,410.65
1,802.96
4,760.53
47,251.46
2,173,195.35
341.92
1,320,775.48
136,938.28
51,170.00
257,293.79
16,991.00
1,033,688.72
110,281.91
10,375,753.66
1,320,775.48
136,938.28
51,170.00
257,293.79
16,991.00
1,033,688.72
110,281.91
10,375,753.66
308,324.47
13,256.91
10,694.02
811.96
8,559.83
50,093.14
1,434.08
2,131.93
238.11
52,500.00
22,450.71
3,166.70
1,960.06
3,271,123.10
296,978.57
2 031 73
5,473.56
498.48
20.00
1,735.79
2,374.39
1,874,770.30
329.086.67
12,004.46
8,579.83
53,263.01
2,370.04
77,325.10
5,126.76
5,442,871.97
313,276.52
231,619.45
34,953.02
55,732.50
19,269.84
10,750.22
6,727.56
70,410.65
57,114.55
1,055.77
4,760.53
2,101.61
368,952.35
36,874.74
837.88
47,251.46
7,639.27
2,173,195.35
883,459.87
171,744.85
579,848.99
75,002.34
17,477.78
128,580.97
6,862.14
406,664.97
54,890.73
3,228,400.07
209,677.48
109,461 97
9,305.98
11,553.05
45,994.91
1,368.07
92,499.99
44,819.73
412,378.93
4,833.30
947,902.02
648,954.49
92,700.37
40,625.50
13,559.34
29,454.90
6,390.75
45,431.12
107,625.11
411,839.82
49,931.48
25,112.39
75,449.81
7,758.82
549,698.65
50,264.42
1,704,481.66
1,320.775.48
136,938.28
51,170.00
257,293.79
16,991.00
1,033,688.72
110,281.91
10,375,753.66
24.5
14.8
21.2
28.5
19.4
11.6
8.1
66.3
304
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Balance Sheets of Electrical Departments of
NIAGARA
SYSTEM— Continued
Municipality
Population
Harriston
1,293
Harrow
926
Hensall
719
Hespeler
2,784
Highgate
338
Assets
Lands and buildings
$ c.
$ c.
$ c.
$ c.
4,474.73
29,732.13
30,580.07
$ c.
Substation equipment
Distribution system — overhead . . .
Distribution system — underground
Line transformers
Meters
Street light equipment, regular. . . .
Street light equipment, ornamental
Miscellaneous construction expense
Steam or hvdraulic plant
600.00
21,945.86
16.655.54
12,370.10
6,383.76
7,416.42
7,087.97
1,192.80
9.910.52
5,831.12
741.63
4,428.42
3,427.82
612.83
20,634.74
12,264.99
7,147.63
2,109.25
1,697.12
453.91
892.07
303.39
549.80
603.89
513.64
Old plant
1,001.43
400.00
Other plants not distributed
Total plant
40,136.55
431.61
33,442.20
6,274.16
21,788.97
3,475.78
4,000.00
47.20
105,438.18
2,570.18
"4,734.05
435.36
11,157.68
Bank and cash balance
2,263.07
Securities and investments
2,305.54
Accounts receivable
Inventories
338.14
58.48
297.16
238.14
Sinking fund on local debentures. .
Equity in H-E.P.C. systems
Other assets
19,021.07
11,158.25
8,596.60
56,882.64
5,893.16
Total assets
Deficit
59,985.85
51,171.77
37,908.55
170,060.41
21,857.59
Total
59,985.85
51,171.77
37,908.55
170,060.41
21,857.59
Liabilities
Debenture balance
Accounts payable
Bank overdraft
10,235.76
3,471.46
8.251.50
2,816.72
7,130.11
849 . 78
34,897.47
184.74
3,050.55
Other liabilities
406 . 24
55.50
5.00
Total liabilities
13,707.22
11,474.46
8,035.39
35,087.21
3,050.55
Reserves
For equity in H-E.P.C. systems .- . .
For depreciation
19,021.07
5,676.17
11,158.25
1,471.04
8,596.60
5,832.73
56,882.64
12,465.85
500.00
5,893.16
3,333.64
Total reserves
24,697.24
12,629.29
14,429.33
69,848.49
9,226.80
Surplus
Debentures paid
15,582.27
3,748.50
4,869 89
42,673.04
1,949.45
Operating surplus
5,999.12
23,319.52
10,573.94
22,451.67
7,630.79
Total surplus
21,581.39
27,068.02
15,443.83
65,124.71
9,580.24
Total liabilities, reserves and surplus
59,985.85
51.171.77
37,908.55
170,060.41
21,857.59
Percentage of net debt to total assets
33.5
28.6
27.4
31.0
19.1
1934
HYDRO-ELECTRIC POWER COMMISSION
305
"A"— Continued
Hydro Municipalities as at December 31, 1933
H umber-
stone
2,265
Ingersoll
5,296
Jarvis
504
Kingsville
2,286
Kitchener
31,443
Lambeth
P.V.
La Salle
600
Leaming-
ton
5,025
$ c.
$ c.
15,064.45
33,210.77
55,296.05
$ c.
$ c.
7,774.09
$ c.
179,685.67
218,733.96
313,555.64
38,019.52
172,698.35
180,742.56
64,926.44
86,939.84
20,676.96
$ c.
$ c.
$ c.
16,387 58
7,085 62
26,146.68
9,408.06
31,259.00
6,931.29
18,971 .34
49,897.49
11,971 67
9,181.25
7,621.55
884.80
27,142.19
24,764.88
3,980.93
4,597.59
11,236.70
3,080.21
2,358.05
846.99
13,218.19
13,260.75
1,439.82
19,200.00
52.50
1,883.12
2,184.61
269.16
6,716.60
4,174.22
946.49
22,592.47
22,504.36
1,380.13
15,178 49
3,167.04
707.52
300.71
1,660.69
1,838.17
19,098.54
52,363.91
47,001.32
3,986 70
194,392.10
16,400.83
3,951.34
86,204.35
8,568.14
8,000.00
544.48
1,328,342.85
11,568.89
1,530.06
3,000.00
231.98
32,469.34
7,165.32
1,144.49
148,835.98
7,060 52
11,716.57
1,620.07
1,474.48
68,029.84
105,017.04
761.03
15,000.00
50,628.45
10,763.23
11,000.00
452.04
203.05
785.96
9,735.62
1,138 44
7,844.51
21,171.01
704,233.55
5,287.52
6,920.00
1,361.14
38,294.17
62,314.12
383,011.13
28,399.73
124,487.98
2,108,968.08
21,618.45
49,060 . 29
205,976.63
62,314.12
383,011.13
28,399.73
124,487.98
2,108,968.08
21,618.45
49,060.29
205,976.63
19,200.00
169.07
79,800.00
10,172.70
5,330.73
5,358.62
6,622.83
1,510.97
28,630.70
3,155.02
190,441.49
48,568.96
42,547.99
88,094.26
2,436 29
648.04
11,329.59
14.00
33,005.45
331.10
917.09
20,882.22
30.00
381.03
17,416.05
20,286.16
100,662.05
8,133.80
52,667.94
369,652.70
3,114.33
11,724.62
50,752.60
9,735.62
1,332.06
105,017.04
12,343.29
857.40
7,844.51
2,211.32
21,171.01
14,531.37
704,233.55
247,520.58
26,164.18
5,287.52
2,854.95
6,920.00
5,247.44
980.11
38,294.17
19,175.90
11,067.68
118,217.73
10,055.83
35,702.38
977,918.31
8,142.47
13,147.55
57,470.07
12,800.00
3,877.17
4,869.30
321,708.51
1,563.71
4,170.41
14,994 55
68,029.84
96,101.51
18,160.28
6,332.93
31,248.36
439,688.56
8,797.94
20,017 71
82,759.41
30,960.28
164,131.35
10,210.10
36,117.66
761,397.07
10,361.65
24,188.12
97,753.96
62,314.12
383,011.13
28,399.73
124,487.98
2,108,968.08
21,618.45
49,060.29
205,976.63
38.6
13.0
39.6
39.7
21.4
19.0
27.8
23.3
306
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Balance Sheets of Electrical Departments of
NIAGARA
SYSTEM— Continued
Municipality
Listowel
2,665
London
73,173
London
Twp.
Long
Branch
3,541
Lucan
Population
590
Assets
Lands and buildings
$ c.
1,457.39
"38,677.84
2,897.25
17,556.07
15,946.16
1,853.82
1,348.66
2,482.88
$ c.
446,297.17
937,035.75
775,097.74
281,865.17
288,604.36
322,834.22
66,972.71
84,746.73
87,103.97
$ c.
$ c.
$ c.
Substation equipment
Distribution system — overhead . . .
Distribution system — underground
17,172.37
51,871.03
10,528.36
Line transformers
5,605.28
3,782.72
861.36
11,667.28
16,685.36
4,212.21
4,131 49
Meters
3,123 36
Street light equipment, regular. . . .
Street light equipment, ornamental
Miscellaneous construction expense
Steam or hydraulic plant
430.15
518.96
1,220.51
455.52
Old plant
4,745.30
1,733.80
2,860 45
Other plants not distributed
Total plant
86,965.37
13,684.45
3,290,557.82
82,325.47
29,674.49
5,179.48
85,656.39
21 529 33
Bank and cash balance
3,654.23
Securities and investments
5,000.00
Accounts receivable
398.63
199,081.27
81,210.59
323,711.25
1,276,199.72
430.86
1,606.66
1,031.58
5.30
Inventories
Sinking fund on local debentures. .
Equity in H-E.P.C. systems
Other assets
40,935.07
7,958.96
112.32
6,340.04
2,362.03
11,298.71
Total assets
141,983.52
5,253,516.98
44,531.91
95,390.04
41,487.57
Deficit
Total
141,983.52
5,253,516.98
44,531.91
95,390.04
41,487.57
Liabilities
Debenture balance
7,689.73
3,219.79
917,970.20
123,527.12
11,006.23
6.69
25,368.14
12,506.99
4,324.21
Accounts payable
171.52
Bank overdraft
Other liabilities
1,545.04
85,177.59
112.32
2,362.03
147.22
Total liabilities
12,454.56
1,126,674.91
11,125.24
40,237.16
4,642 "95
Reserves
For equity in H-E.P.C. systems . . .
For depreciation
40,935.07
27,324.72
1,276,199.72
815,940.62
79,389.72
7,958.96
4,290.81
6,340.04
13,202.97
359.98
11,298.71
7,141.45
Other reserves
Total reserves
68,259.79
2,171,530.06
12,249.77
19,902.99
18,440.16
Surplus
Debentures paid
35,500.16
663,929.80
323,711.25
967,670.96
7,993.77
14,936.46
6,889.41
Local sinking fund
Operating surplus
25,769.01
13,163.13
20,313.43
11,515.05
Total surplus
61,269.17
1,955,312.01
21,156.90
35,249.89
18,404.46
Total liabilities, reserves and surplus
141,983.52
5,253,516.98
44,531.91
95,390.04
41,487.57
Percentage of net debt to total assets
11.1
20.2
30.2
43.6
15.4
1934
HYDRO-ELECTRIC POWER COMMISSION
307
"A"— Continued
Hydro Municipalities as at December 31, 1933
Lynden
P.V.
Markham
1,073
Merlin
P.V.
Merritton
2,544
Milton
1,828
Milverton
1,004
Mimico
6,454
Mitchell
1,571
$ c.
241 18
$ c.
% c.
$ c.
2,951.67
32,689.04
34,597.79
$ c.
$ c.
237.20
$ c.
17,071.16
38,461.02
74,219 93
$ c.
19,388.71
11,868.94
20,602.04
21,287.83
4,774.11
15,421.16
8,042.18
11,341.16
28,998.95
2,134.21
1,595.60
340.66
7,872.35
5,681.24
750.76
3,399.23
2,057.70
555.64
7,320.28
9,664.77
4,676.11
13,944.73
13,091.00
1,282.36
7,565.80
5,047.01
737.16
29,920.12
28,091.34
7,747.29
8,807.77
11,902.61
3,698.59
193.57
1,560.51
455.36
3,210.44
4,282.62
773.05
5,008.13
931.79
241.85
3,092.54
1,500 00
9,279.33
866 . 20
31,286.02
1,963.31
2,153.58
696.00
14,751.96
3,007.41
6,000.00
712.68
95,110.10
6,854.90
68,164.23
5,363.01
12,000.00
5,708.73
4,145.51
25,701.38
1,036.76
2,000.00
1,689.76
200,518.99
100.00
96,516.25
2,903.68
1,000.00
394 . 72
3,538.18
10,6i0.69
5,769.11
2,544.29
8,470.87
9,223.04
7,210.65
51,801.81
62,216.95
139.85
27,538.79
74,423.84
2,012.47
25,154.35
19,011.12
45,321.95
31,682.70
157,304.99
157,738.28
57,966.69
287,665.99
133,887.68
19,011.12
45,321.95
31,682.70
157,304.99
157,738.28
57,966.69
287,665.99
133,887.68
30
1,327.05
728.19
1,109.85
2,675.00
229.03
1,010.65
4,645.00
280.76
368.49
65.00
139.85
106.00
2,946.63
1,307.00
9,075.11
20,792.13
9,561.09
4,141.31
89,139.33
474.49
2.447.13
5,420.72
2,150.45
5,720.91
14,462.53
1,492.45
5,125.26
675.00
41,430.43
2,749.18
33,537.39
1,829.13
10,131.93
5,616.15
12,122.27
24,735.02
8,033.69
43,745.35
22,295.22
3,317. 3e
19,239. U
7,630.34
66,867.87
45,270.24
12,452.64
36,177.86
52,426.23
5,146.45
29,371.15
13,246.49
78,990 . 14
70,005.26
20,486.33
79,923.21
74,721.45
19,011.12
45,321. 9<
31.682.7C
157,304.95
157,738.28
57,966.65
287,665.99
133,887.68
27.9
3.6
37.0
19.7
9.8
13.6
41.8
0.4
308
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Balance Sheets of Electrical Departments of
NIAGARA
SYSTEM— Continued
Municipality
Moorefield
P.V.
Mount
Brydges
P.V.
Newbury
267
New
Hamburg
1,426
New
Population
Toronto
7,280
Assets
Lands and buildings
$ c.
$ c.
$ c.
$ c.
2,513.19
1,167.55
23,632.05
$ c.
43,745.98
Substation equipment
Distribution system — overhead . . .
Distribution system — underground
Line transformers
2,980.96
6,393.68
6,422.17
77,754.15
8,605.69
990 . 72
1,202.26
295.88
1,709.69
2,240.12
689.49
1,797.86
1,187.32
817.42
6,512.94
8,982.53
2,065.70
29,638.15
Meters
28,094.55
Street light equipment, regular. . . .
Street light equipment, ornamental
Miscellaneous construction expense
Steam or hydraulic plant
10,090.44
348.35
220.32
486.13
1,083.83
7,428.83
Old plant
348.22
5,242.56
Other plants not distributed .
Total plant
5,818.17
2,099.55
11,253.30
2,774.13
3,000.00
719.98
11,059.12
773.06
51,200.35
25.00
205,357.79
Bank and cash balance
Securities and investments
50.00
Accounts receivable
Inventories
8.64
867.12
1,045.55
1,044.07
22,695.89
Sinking fund on local debentures
Equity in H-E.P.C. systems
Other assets
3,564.98
3,954.00
2,459.74
28,962.42
233,643.69
1,089.07
Total assets
11,491.34
21,701.41
15,159.04
82,277.39
462,836.44
Deficit
Total
11,491.34
21,701.41
15,159.04
82,277 39
462,836.44
Liabilities
Debenture balance
1,339.73
171.93
2,349.77
31.45
4,400.00
6,775.48
4,018.49
Accounts payable . .
412.37
Bank overdraft . .
349.48
119.50
13,987.00
Other liabilities
70.00
5.00
5,089.07
Total liabilities
1,511.66
2,451.22
4,405.00
7,244.46
23,506.93
Reserves
For equity in H-E.P.C. systems. . .
For depreciation
3,564.98
2,044.16
3,954.00
2,115.30
2,459.74
2,343.93
28,962.42
10,464.13
192.10
233,643.69
40,978.95
Other reserves
3,094.82
Total reserves
5,609.14
6,069.30
4,803.67
39,618.65
277,717.46
Surplus
Debentures paid
3,160.27
1,870.23
5,354.39
10,953.60
3,981.51
Local sinking fund
Operating surplus
1,210.27
11,310.66
595.98
24,460.68
157,630.54
Total surplus
4,370.54
13,180.89
5,950.37
35,414.28
161,612.05
Total liabilities, reserves and surplus
11,491.34
21,701.41
15,159.04
82,277.39
462,836.44
Percentage of net debt to total assets
19.1
13.8
34.7
13.6
10.2
1934
HYDRO-ELECTRIC POWER COMMISSION
309
"A"— Continued
Hydro Municipalities as at December 31 , 1933
Niagara
Falls
18,507
Niagara-
on-the-Lake
1,672
North York
Twp.
Norwich
1,126
Oil Springs
433
Otterville
P.V.
Palmerston
1,617
Paris
4,330
$ c.
132,198.34
$ c.
2,307.35
16,048.36
27,556.88
$ c.
28,248.83
$ c.
4,157.99
$ c.
1,296.76
$ c.
$ c.
$ c.
8,426.83
229,660.23
691.88
26,298.27
27,948.18
190,325.96
328,051.79
11,050.93
12,840.49
7,068.45
51,352.12
157,091.98
106,984.98
117,345.32
6,852.78
7,707.66
1,230.44
79,115.36
41,099.94
156.00
13,491.21
20,507.44
6,180.85
6,818.57
4,685.64
5,670.91
3,321.76
308.24
3,587.82
2,227.30
1,408.96
9,844.50
7,414.82
2,179.10
19,712.59
19,291.30
13,986.43
14,475.01
1,716.72
1,585.11
2,568.33
142.00
781.39
731.08
21,604.27
3,509.82
4,018.71
969,686.09
27,754.32
63,420.19
744.73
510,670 57
37,988.91
2,185.73
3,000.00
1,846.81
1,285.36
26,006.49
3,055.32
2,483.98
753.59
74.77
14,434.53
3,548.17
51,228.67
315.28
141,448.53
5,489.68
4,304.59
. 6,321.28
82.97
18,500.00
21,267.90
16,116.47
2,412.18
1,448.52
884.28
341.95
121.30
838.78
322,289.01
25,951.10
16,284.04
52.05
49,580.68
21,467.24
14,703.00
4,586.52
24,034.50
65,116.46
1,383,064.89
84,361.71
570,960.09
67,774.05
47,077.15
23,453.50
76,041.70
231,393.45
1,383,064.89
84,361.71
570,960.09
67,774.05
47,077.15
23,453.50
76,041.70
231,393.45
351,446.59
50,114.43
21,359.37
565.87
371,831.09
223.18
6,024.98
223.63
4,945.29
1,507.58
719.34
256.93
4,157.76
724.44
9,461.15
548.79
14,997.41
50.00
18,633.22
107.50
10.00
237.50
416,558.43
21,975.24
390,687.49
6,356.11
6,452.87
986.27
5,119.70
10,009.94
322,289 01
135,074.09
11,097.41
16,284.04
8,728.32
49,580.68
56,045.34
21,467.24
4,828.54
1,000.00
14,703.00
6,123.17
4,586.52
3,953.07
24,034.50
6,287.98
491.67
65,116.46
58,963.83
175.00
468,460 51
25,012.36
105,626.02
27,295.78
20,826.17
8,539.59
30,814.15
124,255.29
338,796.41
15,142.05
71,190.78
7,731.02
11,776.02
3,780.66
22,842.24
82,538.85
159,249.54
22,232.06
3,455.80
26,391.14
8,022.09
10,146.98
17,265.61
14,589.37
498,045.95
37,374.11
74,646.58
34,122.16
19,798.11
13,927.64
40,107.85
97,128.22
1,383,064.89
84.361.71
570,960.09
67,774.05
47,077.15
23,453.50
76,041.70
231,393.45
39.2
32.3
73.0
13.7
19.9
5.2
9.8
6.0
310
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Balance Sheets of Electrical Departments of
NIAGARA
SYSTEM— Continued
Municipality. .
Parkhill
998
Petrolia
2,569
Plattsville
P.V.
Point
Edward
1,211
Port
Population
Colborne
6,006
Assets
Lands and buildings
$ c.
$ c.
900.00
2,403.55
43,154.86
$ c.
$ c.
$ c.
22,561.01
Substation equipment
Distribution system — overhead . . .
Distribution system — underground
Line transformers
15,970.73
4,116.10
21,201.15
88,265.47
4,239.63
4,284.93
898 . 23
26,133.29
14,951.86
4,849.35
1,890.66
1,921.31
147.15
6,752.07
4,938.70
3,060.75
24,486.11
Meters
21,939.13
Street light equipment, regular. . . .
Street light equipment, ornamental
Miscellaneous construction expense
Steam or hydraulic plant
4,544.86
16,611.59
1,364.13
5,567.23
535.92
503.14
7,355.75
Old plant
3,389.94
9,929.60
Other plants not distributed
Total plant
26,757.65
1,324.87
101,350.08
5,040.77
8,400.00
4,845.31
1,113.27
8,611.14
598.90
" ' 290 ' 63
36,455.81
339.69
13,000.00
3,731.10
195.693.52
2,030.85
1,500.00
Accounts receivable
211.30
10,700.96
3,562.98
Sinking fund on local debentures. .
Equity in H-E.P.C. systems
10,093.35
58,101.13
607.00
5,100.27
25,866.17
49,150.47
Total assets
38,387.17
179,457.56
14,600.94
79,392.77
262,638.78
Deficit
Total
38,387.17
179,457.56
14,600.94
79,392.77
262,638.78
Liabilities
Debenture balance
6,053.94
24,250.57
2,655.90
2,829.93
7,995.2?
1,973.33
93,441.20
7,259.53
75.00
607.00
20,244.27
6,128.94
27,513.47
2,829.93
9,968.55
120,945.00
Reserves
For equity in H-E.P.C. systems. . .
For depreciation
10,093.35
5,061.97
58,101.13
26,730.46
462.12
5,100.27
2,805.33
25,866.17
8,646.12
300.00
49,150.47
30,837.14
1,424.82
Total reserves
15,155.32
85,293.71
7,905.60
34,812.29
81,412.43
Debentures paid
8,576.08
25,749.43
2,407.07
9,004.78
52,558.80
Operating surplus
8,526.83
40,900.95
1,458.34
25,607.15
7,722.55
Total surplus
17,102.91
66,650.38
3,865.41
34,611.93
60,281.35
Total liabilities, reserves and surplus.
38,387.17
179,457.56
14,600.94
79,392.77
262,638.78
Percentage of net debt to total assets
21.7
22.3
29.8
18.6
52.9
1934
HYDRO-ELECTRIC POWER COMMISSION
31
"A"— Continued
Hydro Municipalities as at December 31, 1933
Port
Credit
1,650
Port
Dalhousie
1,331
Port
Dover
1,680
Port
Rowan
674
Port
Stanley
723
Preston
6,138
Princeton
P.V.
Queenston
P.V.
$ c.
675.00
$ c.
$ c.
248.75
$ c.
$ c.
1,570.80
$ c.
$ c.
$ c.
50,602.15
90,548.28
24,693.75
18,560.05
29,878.70
9,650.37
20,483.81
4,228.15
7,594.07
9,881.98
9,266.13
4,922.71
9,272.89
9,380.26
1,041.19
10,285.81
6,959.06
2,621.53
1,676.62
1,815.68
888.04
11,456.32
9,348.18
1,619.18
47,835.53
38,805.22
5,418.03
2,473.48
1,223.65
185.35
1,911.85
1,536.99
422.43
880.99
2,304.88
2,418.27
701.53
5,795.39
6,948.89
64.35
2,081.11
6,018.38
577.51
32,126.75
50,320.56
3,030.30
46,577.65
1,564.01
3,000.00
2,472.02
52,412.12
4,526.71
14,732.24
86.36
50,851.19
3,532.64
3,000.00
1,359.00
272,284.85
16,822.25
6,000.00
15,974.69
225.63
8,174.98
2,211.42
13,546.45
132.20
1,806.68
3,167.51
256.29
1,030.52
269.27
2,763.77
16,815.86
19,681.98
402.42
12,733.61
3,408.20
22,072.23
155,142.27
4,534.68
3,708.42
75,241.94
73,193.31
72,839.95
18,483.09
6,119.26
80,815.06
466,449.69
15,951.60
17,656.34
75,241.94
73,193.31
72,839.95
24,602.35
80,815.06
466,449.69
15,951.60
17,656.34
8,150 07
2,886.10
9,830.08
187.03
10,502.73
3,517.26
8,914.18
8,410.10
7,406.13
655.00
51,651.54
6,720.30
1,918.27
110.75
5,635.49
38.97
370.00
642.50
30.01
1,317.94
11,406.17
10,017.11
14,662.49
17,324.28
. 8,091.14
59,689.78
2,029.02
5,674.46
19,681.98
13,033.01
198.71
16,815.86
4,352.20
800.00
12,733.61
7,809.93
3,408.20
1,784.05
22,072.23
9,232.04
155,142.27
93,620.87
103.59
4,534.68
2,287.98
3,708.42
2,540.45
32,913.70
21,968.06
20,543.54
5,192.25
31,304.27
248,866.73
6,822.66
6,248.87
6,349.93
12,669.92
2,763.77
25,774.45
18,497.27
2,085.82
11,543.87
101,148.46
1,631.73
3,864.51
24,572.14
19,136.65
29,875.78
56,744.72
5,468.19
1,868.50
30,922.07
41,208.14
37,633.92
2,085.82
41,419.65
157,893.18
7,099.92
5,733.01
75.241.94
73,193.31
72,839.95
24,602.35
80,815.06
466,449.69
15,951.60
17,656.34
20.5
13.5
24.4
114.9
13.8
19.2'
17.8
40.7
312
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Balance Sheets of Electrical Departments of
NIAGARA
SYSTEM— Continued
Municipality
Population
Richmond
Hil
1,270
Ridgetown
1,942
Riverside
5,125
Rockwood
P.V.
Rodney
757
Assets
Lands and buildings
$ c.
$ c.
$ c.
2,379.31
$ c.
79.00
$ c.
Substation equipment
Distribution system — overhead . . .
Distribution system — underground
Line transformers
Meters
Street light equipment, regular. . . .
Street light equipment, ornamental
Miscellaneous construction expense
Steam or hydraulic plant
600.00
10,471.67
1,024.24
21,427.18
90,947.15
7,565.39
11,203.12
7,803.75
4,754.84
1,334.77
" 35 '. 23
9,768.42
9,403.96
3,533.41
1,431.73
2,379.28
31,354.96
22,650.71
2,481.27
2,802.39
561.22
2,971.48
3,527.15
622.69
17,030.71
4,571.45
455.65
771.10
Old plant
5,088.46
700.00
Other plants not distributed
Total plant
25,000.26
4,388.52
54,056.68
50.00
13,000.00
574.08
870.21
168,934.29
13,944.92
19,795.54
Bank and cash balance
1,774.92
Securities and investments
3,000.00
Accounts receivable
Inventories
2,574.51
149.92
9,101.58
140.79
114.98
421.61
Sinking fund on local debentures. .
Equity in H-E.P.C. systems
Other assets
8,304.53
23,153.15
43,095.44
6,373.61
43.15
6,962.59
Total assets
40,417.74
91,704.12
221,131.31
20,617.45
31,954.66
Deficit
Total
40,417.74
91,704.12
221,131.31
20,617.45
31,954.66
Liabilities
Debenture balance
Accounts payable
Bank overdraft
4,153.98
234.61
6,395.74
1,491.11
2,378.61
335.00
53,888.22
3,945.89
1,550.98
17,030.71
2,345.00
5,332.25
394.84
17.62
41.00
Other liabilities
127.22
140.00
Total liabilities
4,515.81
10,600.46
76,415.80
2,403.62
5,867.09
Reserves
For equity in H-E.P.C. systems. . .
For depreciation
8,304.53
1,319.76
23,153.15
10,897.16
43,095.44
25,990.34
299.70
6,373.61
4,144.31
6,962.59
1,682.26
Other reserves. .
Total reserves
9,624.29
34,050.31
69,385.48
10,517.92
8,644.85
Surplus
Debentures paid
8,046.02
13,060.25
28,611.78
2,155.00
3,167.75
Local sinking fund
Operating surplus
18,231.62
33,993.10
46,718.25
5,540.91
14,274.97
Total surplus
26,277.64
47,053.35
75,330.03
7,695.91
17,442.72
Total liabilities, reserves and surplus
40,417.74
91,704.12
221,131.31
20,617.45
31,954.66
Percentage of net debt to total assets
14.1
13.6
36.8
16.9
23.5
1934
HYDRO-ELECTRIC POWER COMMISSION
313
4 'A"— Continued
Hydro Municipalities as at December 31, 1933
St. Catharines
26,192
St. Clair
Beach
St. George
P.V.
St. Jacobs
P.V.
St. Marys
4,016
St. Thomas
16,275
Sandwich
11,017
$ c.
47,378.92
$ c.
$ c.
$ c.
$ c
3,000.00
26,975.49
56,424.90
$ c.
73,253.59
110,241.39
111,816.38
36,690.67
53,685.43
68,100.59
21,259.32
3,693.04
9,527.13
$ c.
541.70
115,063.83
4,097.56
207,545.05
7,918.75
5,935.34
6,461.28
107,887.10
141,812.77
88,567.66
18,485.98
2,726.36
1,443.71
2,729.42
2,890.56
286.41
2,539.38
2,662 28
390.26
18,843.29
22,018.71
5,074.74
47,269.29
50,421.88
11,665.76
29,486.71
51,239.13
38,196.14
149.27
374.18
460.55
3,790.51
7,938.60
7,792.05
20,696.85
4,148.96
694,329.11
2,678.62
12,238.09
12,215.91
73 . 10
12,513.75
21.37
3,000.00
59.96
156,824.49
25.00
488,267.54
18,521.87
47,758.42
16,627.27
8,962.59
285,209.98
2,295.07
21,659.37
34,500.84
474.38
1,174.22
289.61
24.48
. 3,103.68
3,087.90
1,375.88
76,957.11
18,487.21
393 . 72
68,010.06
290,602.66
3,600.11
7,663.23
7,966.38
264,228.94
125,752.20
20,693.14
1,090,595.67
17,012.42
20,266.33
23,561.46
241,374.06
215.82
844,366.63
474,490.69
1,090,595.67
17,012.42
20,266.33
23,561.46
241,589.88
844,366.63
474,490.69
209,961.24
24,896.78
3,663.73
237.29
345.67
3,344.03
1,759.45
392.27
40,839.90
2,099.66
1,689.09
117.50
27,957.27
4.60
97,856.41
14,000.00
29,792.71
87.50
12,188.74
82,478.25
278,650.73
4,246.69
3,431.53
2,151.72
44,746.15
40,150.61
180,334.66
290,602.66
133,334.99
7,047.10
3,600.11
2,298.68
12.67
7,663.23
1,874.75
7,966.38
2,758.05
76,957.11
44,444.57
659.05
264,228.94
97,309.67
487.21
125,752.20
37,335.30
430,984. 75
5,911.46
9,537.98
10,724.43
122,060.73
362,025.82
163,087.50
92,061.67
68,010.06
2,677.72
2,655.97
4,240.55
73,407.12
1,375.88
110,986.80
47,716.62
220,888.46
4,176.55
4,640.85
6,444.76
331,203.40
83,351.91
380,960.19
6,854.27
7,296.82
10,685.31
74,783.00
442,190.20
131,068.53
1,090,595.67
17,012.42
20,266.33
23,561.46
241,589.88
844,366.63
474,490 . 69
32.3
31.6
27.2
13.8
26.6
6.3
43.4
314
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Balance Sheets of Electrical Departments of
NIAGARA
SYSTEM— Continued
Municipality
Sarnia
17,801
Scarboro'
Twp.
Seaforth
1,692
Simcoe
5,397
Spring-
field
379
Population
Assets
Lands and buildings
$ c.
111,796.86
199,300.27
214,746.25
$ c.
16,585.49
301.95
269,600.83
$ c.
1,290.34
5,999.16
28,114.36
$ c.
8,442.41
22,906.67
50,178.74
1,417.87
24,481.89
24,074.70
5,589.97
3,500.00
6,016.27
$ c.
Substation equipment
Distribution system — overhead . . .
Distribution system — underground
Line transformers
Meters
7,872.62
79,089.95
71,879.72
25,306.78
7,482.11
24,057.28
59,762.65
63,913.90
19,810.03
9,670.10
8,749.87
1,414.55
2,374.19
1,981.74
Street light equipment, regular. . . .
Street light equipment, ornamental
Miscellaneous construction expense
Steam or hydraulic plant
546.24
12,685.69
574.76
691.36
Old plant
55,445.72
927.92
Other plants not distributed
Total plant
789,104.94
2,683.40
442,660.54
32,297.54
55,813.14
2,455.26
100.00
5,728.70
2,362.54
147,536.44
8,571.22
13,466.15
Bank and cash balance
62.84
Securities and investments
4,500.00
Accounts receivable
41,545.26
19,011.08
13,062.13
2,564.49
112.00
851.04
Inventories
Sinking fund on local debentures
Equity in H-E.P.C. systems
Other assets
328,029.30
3,520.00
84,438.89
37,447.48
49,310.53
5,308.21
Totals assets
1,183,893.98
572,459.10
103,907.12
208,094.68
24,188.24
Deficit ....
Total
1,183,893.98
572,459.10
103,901.12
208,094.68
24,188.24
Liabilities
Debenture balance .
129,466.79
22,802.79
219,448.13
26,383.30
54,937.81
591.45
3,610.93
Accounts payable
Bank overdraft
316.44
65.49
Other liabilities
13,391.67
25,952.79
35.00
3,625.00
52.00
Total liabilities
165,661.25
271,784.22
351.44
59,154.26
3,728.42
Reserves
For equity in H-E.P.C. systems. . .
For depreciation
328,029.30
116,801.40
944.69
84,438.89
63,544.07
4,202.94
37,447.48
18,367.28
1,106.96
49,310.53
18,402.37
5,308.21
2,330.06
Other reserves
Total reserves
445,775.39
152,185.90
56,921.72
67,712.90
7,638.27
Surplus
Debentures paid
208,533.21
71,120.15
25,000.00
20,497.09
5,889.07
Local sinking fund
Operating surplus. .
363,924.13
77,368.83
21,633.96
60,730.43
6,932.48
Total surplus .
572,457.34
148,488.98
46,633.96
81,227.52
12,821.55
Total liabilities, reserves and surplus
1,183,893.98
572,459.10
103,907.12
208,094.68
24,188.24
Percentage of net debt to total assets
18.0
55.7
0.5
35.7
19.7
934
HYDRO-ELECTRIC POWER COMMISSION
315
"A"— Continued
Hydro Municipalities as at December 31, 1933
Stamford
Twp.
Stouffville
1,105
Stratford
18,869
Strathroy
2,879
Sutton
809
Tavistock
1,042
Tecumseh
2,546
Thames-
ford
P.V.
$ c.
7.196.71
$ c.
$ c
135,191.94
136,903.19
153,378.90
$ c.
8,741.01
22,194.32
48,919.46
$ c.
$ c.
234.02
$ c.
$ c.
37,384.60
124,563.22
12,608.07
19,752.18
13,273.34
34,572.41
7,691.45
43,451.31
30,693.29
9,191.78
3,903.57
4,108.78
1,445.52
93,765.92
85,894.94
21,797.39
19,238.16
14,441.11
5,814.75
6,797.85
5,633.71
1,571.88
6,251.28
4,786.61
931.82
10,039.18
10,501.08
2,625.63
2,549.77
290.65
4,760.95
1,262.48
10 : 164.65
497.41
17,534.24
2,293.90
1,593.88
586.46
343.89
13,743.66
3,866.37
16,150.00
12,343.15
675.00
276,389.22
4,654.19
26,429.72
4,165.17
5,000.00
439.03
27.20
660,616.52
30,599.19
21,900.00
29,556.48
9,679.56
209,445.54
341,228.19
2,283.71
133,985.86
8,514.85
36,024.50
2,403.39
26,063.53
854.69
3,596.30
766.81
61,136.10
13,501.39
626.47
7,500.00
14,089.24
3,546.01
2,536.70
1,385.47
21.00
2,886.87
7,185.81
48,099.73
5.170.62
7,758.09
47,541.31
541.59
7,140.47
24,238.67
13,344.22
9,606.22
34.00
355,588.81
43,819.21
1,305,309.19
196,666.32
46,974.83
55,520.00
77,367.19
31,268.08
355.588.81
43,819.21
1,305,309.19
196,666.32
46,974.83
55,520.00
77,367.19
31,268.08
171,033.8/
10,205.15
6,628.45
412,000.00
54.64
34,437.54
192.76
16,291.56
2,266.91
3,666.42
105.83
14,789.20
3,250.03
3,928.24
4,760.95
1,662.13
76.48
4,073.36
2,283.71
541.59
47.30
34.00
185,312.38
6,628.45
414,338.35
35,171.89
18,605.77
3,772.25
26,728.42
1,772.61
48,099.73
23,104.62
2,375.00
7,758.09
2,075.19
341,228.19
208,434.19
2,024.65
47,541.31
21,936.81
522.15
7,140.47
4,860.12
24,238.67
7,536.71
13,344.22
10,279.95
214.95
9,606.22
4,517.18
73,579.35
9,833.28
551,687.03
70,000.27
12,000.59
31,775.38
23,839.12
14,123.40
69,244.30
11,911.82
43,800.00
209,445.54
86,038.27
31.794.46
9,708.44
2,333.58
11,210.80
3,695.90
27,452.78
15,445.66
59,699.70
6,660.03
17,638.79
15,588.85
11,676.17
96,697.08
27,357.48
339,283.81
91,494.16
16,368.47
19,972.37
26,799.65
15,372.07
355.588.81
43,819.21
1,305,309.19
196,666.32
46,974.83
55,520.00
77,367.19
31,268.08
60.2
18.4
27.2
23.3
46.7
12.1
37.0
8.0
316
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Balance Sheets of Electrical Departments of
NIAGARA
SYSTEM— Continued
Municipality
Thames-
ville
754
Thedford
577
Thorndale
P.V.
Thorold
5,068
Tilbury
1,996
Population
Assets
Lands and buildings
Substation equipment
$ c.
681.69
$ c.
$ c.
$ c.
9,892.59
$ c.
969.46
Distribution system — overhead . . .
Distribution system — underground
Line transformers
Meters
11,902.59
9,228.39
3,288.86
31,057.12
16,006.41
5,160.49
3,827.61
1,379.42
3,303.91
2,206.01
885.46
1,559.98
1,747.46
181.19
15,052.83
20,502.73
2,811.59
12,699.77
7,440.92
Street light equipment, regular. . . .
Street light equipment, ornamental
Miscellaneous construction expense
Steam or hydraulic plant
1,001.16
895 . 68
1,612.01
310.45
4,982.45
13,244.74
1,426.82
Old plant
4,445.68
433.78
3,049.47
Other plants not distributed
Total plant
28,293.16
2,570.77
6,000.00
576.54
17,669.56
410.78
1,000.00
580.65
7,087.94
438.88
97,544.05
4,720.68
42,594.01
Bank and cash balance
3,460.87
Securities and investments
10,000.00
Accounts receivable
605.86
4,122.89
152.13
289.13
Inventories
Sinking fund on local debentures
Equity in H-E.P.C. systems
Other assets .
9,545.28
4,809.74
5,154.87
45,966.73
24,728.27
150.02
Total assets
46,985.75
24,470.73
13,287.55
152,506.48
81,222.30
Deficit .
Total
46,985.75
24,470.73
13,287.55
152,506.48
81,222.30
Liabilities
Debenture balance
4,169.01
11.97
8,933.05
61.82
1,433.12
6,661.95
Accounts payable
152.24
325.40
Bank overdraft
Other liabilities
178.00
10.00
17.50
1,559.50
Total liabilities
4,358.98
9,004.87
1,450.62
1,711.74
6,987.35
Reserves
For equity in H-E.P.C. systems. . .
For depreciation
9,545.28
6,125.55
4,809.74
2,086.53
5,154.87
2,636.99
100.00
45,966.73
23,997.30
24,728.27
10,340.80
Other reserves
Total reserves
15,670.83
6,896.27
7,891.86
69,964.03
35,069.07
Surplus
Debentures paid
7,018.79
7,566.95
1,653.36
5,000.00
7,338.05
Local sinking fund
Operating surplus
19,937.15
1,002.64
2,291.71
75,830.71
31,827.83
Total surplus
26,955.94
8,569.59
3,945.07
80,830.71
39,165.88
Total liabilities, reserves and surplus
46,985 . 75
24,470.73
13,287.55
152,506.48
81,222.30
Percentage of net debt to total assets
11.6
45.8
17.8
1.6
12.4
1934
HYDRO-ELECTRIC POWER COMMISSION
317
"A"— Continued
Hydro Municipalities as at December 31, 1933
Tillson-
burg
3,351
Toronto
626,674
Toronto
Twp.
Trafalgar
Twp.
Area No. 1
Trafalgar
Twp.
Area No. 2
Walkerville
10,681
Wallaceburg
4,343
$ c.
4,824 27
$ c.
5,400,813.30
14,971,090.50
6,227,078.98
4,085,067.76
3,561,045.50
2,974,114.67
480,484 . 65
$ c.
6,366.13
$ c.
$ c.
$ c.
147,518.53
155,069.52
153,627.02
$ c.
37,746.29
13,937 52
9,651.80
41,024.22
175,307.49
20,294.72
10,456.48
55,679.80
16,761.20
15,824.40
11,522 52
49,332.62
31,681.48
3,717.44
9,595.46
4,741.17
2,071.55
1,309.65
90,713.78
69,783.88
34,773.82
19,637.22
10,224.10
187,172.22
38,538.32
4,570.72
2,617,154.43
3,139.02
1,541.60
314.16
4,078.20
3,585,379.99
619.65
18,335.05
20,941.07
108,464.85
540.39
43,902,229.78
387,096.74
270,163.83
6,335.94
10,000.00
8,641.64
36,172.95
1,299.64
4,000.00
572.86
14,151.84
860,758.32
50.00
31,119.99
107,974.17
25,442.15
192,732.30
8,947.86
9,000 00
2,000.00
294 . 10
2,375.17
1,801 45
1,614,289.78
526,939.00
6,121,128.19
10,262,345.03
75,259.49
3,691.60
5,636 29
47,955.04
48,982.20
2,091.46
356,447.26
841.35
102,741.31
2,506.02
1,750.57
172,642.92
62,889,288.01
346,215.07
42,045.45
16,445.94
1,382,633.24
315,499.93
172,642.92
62,889,288.01
346,215.07
42,045.45
16,445.94
1,382,633.24
315,499.93
10,138.34
28 51
26,457,233.36
1,692,448.39
60,920.24
12,614.82
9,461.15
137,772.89
22,305.24
38,468.33
205,072.72
44,546.15
701.54
354.61
2,506.02
2,091.46
1,750.57
12,672.87
28,149,681.75
63,011.70
12,614.82
9,815.76
403,619.18
46,998.26
47,955.04
10,262,345.03
7,214,466.03
968,096.82
48,982.20
85,258.17
862.42
356,447.26
125,031.63
3,454.62
102,741.31
29,731.07
500.00
12,046.67
1,193.00
37,584.12
287.99
78,186.11
18,444,907.88
135,102.79
12,046.67
1,193.00
484,933.51
140,613.42
25,861.66
8,125,766.64
6,121,128.19
2,047,803.55
43,079.76
6,811.59
161,486.11
26,990.43
55,922.28
105,020.82
10,572.37
5,437.18
332,594.44
100,897.82
81,783.94
16,294,698 38
148,100.58
17,383.96
5,437.18
494,080.55
127,888.25
172,642.92
62,889,288.01
346,215.07
42,045.45
16,445.94
1,382,633.24
315,499.93
10.2
47.4
20.6
3.0
59.7
25.8
21.4
318
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Balance Sheets of Electrical Departments of
NIAGARA
SYSTEM— Continued
Municipality
Wardsville
214
Water-
down
924
Waterford
1,168
Waterloo
8,563
Watford
Population
956
Assets
Lands and buildings
$ c.
$ c.
200.00
$ c.
$ c.
14,454.37
63,543.83
90,368.32
$ c.
Substation equipment
Distribution system — overhead . . .
Distribution system — underground
Line transformers
5,003.72
16,056.14
15,772.78
16,452.69
1,665.49
1,253.12
519.36
5,391.05
5,594.64
583.81
7,201.37
5,939.66
3,231.62
40,376.31
34,817.28
14,092.07
3,106.80
6,484.84
5,411.56
Meters
5,200.57
Street light equipment, regular. . . .
Street light equipment, ornamental
Miscellaneous construction expense
Steam or hydraulic plant
807.31
518.73
411.29
447.83
2,022.23
Old plant
193.94
24,160.67
657.44
Other plants not distributed ....
Total plant
9,154.36
28,236.93
2,036.53
32,593.26
349.34
5,300.00
536.95
291,404.49
12,322.16
30,551.80
Bank and cash balance
296.16
Securities and investments
5,500.00
Accounts receivable
974.40
1,457.48
2,170.24
375.00
11,255.78
142,961.10
1,097.07
Inventories
30.87
Sinking fund on local debentures. .
Equity in H-E.P.C. systems
Other assets .
1,876.72
13,365.35
17,475.90
11,763.78
Total assets
12,005.48
45,096.29
56,255.45
460,488.77
49,239.68
Deficit
Total
12,005.48
45,096.29
56,255.45
460,488.77
49,239.68
Liabilities
Debenture balance
3,893.41
200.00
95.95
52,472.72
14,654.51
1,544.99
Accounts payable
400.59
Bank overdraft
Other liabilities
70.00
3,106.80
Total liabilities
4,189.36
70.00
400 . 59
70,234.03
1,544.99
Reserves
For equity in H-E.P.C. systems . . .
For depreciation
1,876.72
1,912.84
13,365.35
6,758.54
17,475.90
8,962.52
142,961.10
93,685.60
328.00
11,763.78
5,596.64
Other reserves
23.00
Total reserves
3,789.56
20,123.89
26,438.42
236,974.70
17,383.42
Surplus
Debentures paid
3,668.99
8,000.00
7,745.53
53,527.28
11,255.78
88,496.98
8,168.22
Local sinking fund
Operating surplus
357.57
16,902.40
21,670.91
22,143.05
Total surplus
4,026.56
24,902.40
29,416.44
153,280.04
30,311.27
Total liabilities, reserves and surplus
12,005.48
45,096.29
56,255.45
460,488.77
49,239.68
Percentage of net debt to total assets
41.4
0.2
1.0
22.1
4.1
1934
HYDRO-ELECTRIC POWER COMMISSION
319
"A"— Continued
Hydro Municipalities as at December 31, 1933
Welland
10,668
Wellesley
P.V.
West Lome
814
Weston
4,736
Wheatley
724
Windsor
65,565
Wood-
bridge
744
Wood-
stock
10,956
73,059.45
56,576.25
11,903.31
32,737.85
60,108.79
312,236.33
678,250.86
754,463.75
141,798.67
343,932.20
329,751.12
37,377.41
693,788.56
125,740.85
35,489.71
' 14,843 '. 74
93,838.15
131,470.15
7,470.91
6,691.79
11,321.69
17,730.00
101,168.78
57,311.64
56,249.15
4,246.63
36,513.75
2,153.50
2,464.94
545.11
4,274.36
3,091.23
643.57
34,379 30
22,587.91
30,041.06
4,443.64
3,887.49
1,659.26
5,776.33
4,273.32
423.26
55,243.46
53,949.56
15,068.12
10,839.08
127.38
347.14
6,313.68
803.82
817.20
2,794.78
50 069 48
1,250.00
2,569.50
141,990.11
483,806.49
4,340.71
30,458.65
11,982.72
320.32
20,927.99
873,55
3,000.00
328.80
198,071.90
5,694.61
28,207.45
3,506.13
1,500.00
227.83
3,559,329.86
33,060.24
112,463.80
133,422.84
84,923.23
120,519.10
1,056,217.61
28,020.11
357.47
' 848.05
18.36
357,552.56
26,166.79
86,000.00
20,702.86
17,893.73
51.17
8,966.00
165.00
3,069.91
374.63
108,771.53
50,999.37
148,814.76
5,169.65
9,904.27
16,699.36
125,872.53
6,384.47
16,082.48
210,352.26
5,564.39
819,958.38
22,258.48
41,829.70
338,770.04
39,825.88
5,099,936.68
45,326.47
740,079.91
819,958.38
22,258.48
41,829.70
338,770.04
39,825.88
5,099,936.68
45,326.47
740,079.91
257,249.38
44,521.42
1,747.84
444.93
5,145.27
103.59
38,410.61
8,199.66
353.07
1,334,783.01
65,350.00
5,040.43
3,052.14
75,894.20
4,589.08
43,233.20
2,155.46
35.00
750,036.31
240.09
5,564.39
345,004.00
2,192.77
5,248.86
40,566.07
8,587.73
2,150,169.32
8,332.66
86,047.67
148,814.76
112,923.96
2,404.87
9,904.27
2,168.34
16,699.36
5,783.14
125,872.53
30,625.81
6,384.47
2,929.42
1,056,217.61
395,106.44
138,012.99
16,082.48
6,628.66
210,352.26
125,853.55
13,134.05
264,143.59
12,072.61
22,482.50
156,498.34
9,313.89
1,589,337.04
22,711.14
349,339.86
41,750.62
5,752.16
2,854.73
31,621.83
4,800.34
655,217.02
584,694.20
3,459.54
51,491.43
60,288.64
2,240.94
11,243.61
110,083.80
17,123.92
10,823.13
14,282.67
202,201.58
210,810.79
7,993.10
14,098.34
141,705.63
21,924.26
1,360,430.32
304,692.38
819,958.38
22,258.48
41,829.70
338,770.04
39,825.88
5,099,936.68
45,326.47
740,079.91
48.6
17.7
20.8
19.0
25.7
43.4
28.5
6.2
320
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Balance Sheets of Electrical Departments of
NIAGARA
SYSTEM— Concluded
Municipality
Wyoming
482
York Twp.
Zurich
P.V.
NIAGARA
Population
SYSTEM
SUMMARY
Assets
Lands and buildings
$ c.
$ c.
$ c.
$ c.
8,824,114.16
20,837,708.34
16,955,410.84
5,556,486 79
Substation equipment
Distribution system — overhead. . . .
Distribution system — underground
Line transformers
7,336.07
772,073.02
6,932.37
. 1,257.61
2,311.10
289.62
1,643.52
2,270.21
471.82
8,154,866.70
6,936,257.77
1,744,843.70
1,458,443.68
3,663,846.72
13,244 74
Meters
Street light equipment, regular ....
Street light equipment, ornamental
Miscellaneous construction expense
Steam or hydraulic plant
49,765.60
805 . 20
19,070.96
240.77
Old plant
150.00
4,403,238.16
200,000.00
Other plants not distributed
Total plant
11,999.60
32.20
840,909.58
94,214.56
11,708.69
1,291.14
2,000.00
13.86
78,748,461.60
1,354,901.08
735,567.45
3,182,004.70
Bank and cash balance
Securities and investments
Accounts receivable
315.44
13,089.47
Inventories
1,076,929.55
Sinking fund on local debentures. . .
8,016,069.90
Equity in H-E.P.C. systems
Other assets
4,467.98
45.00
7,563.75
23,196,330.36
19,420.29
249,586.23
Total assets
16,860.22
2,112.46
967,633.90
22,577.44
116,559,850.87
Deficit
14,494.35
Total
18,972.68
967,633.90
22,577.44
116,574,345.22
Liabilities
Debenture balance
1,639.52
307.06
409,365.43
32,498.52
3,742.80
302.04
38,275,850.97
Accounts payable
2,805,142.07
Bank overdraft
154,550.92
Other liabilities
45.00
16.02
3,724,456.24
Total liabilities
1,991.58
441,863.95
4,060.86
44,960,000 . 20
Reserves
For equity in H-E.P.C. systems. . . .
For depreciation
4,467.98
4,452.64
7,563.75
4,025.25
23,196,330.36
146,967.70
13,330,347.14
Other reserves
1,589,857.32
Total reserves
8,920.62
146,967.70
11,589.00
38,116,534.82
Surplus
Debentures paid
8,060.48
190,634.57
1,848.81
14,911,550.87
Local sinking fund
8,016,069.90
Operating surplus
188,167.68
5,078.77
10,570,189.43
Total surplus
8,060.48
378,802.25
6,927.58
33,497,810.20
Total liabilities, reserves and surplus
18,972.68
967,633.90
22,577.44
116,574,345.22
Percentage of net debt to total assets
32.8
45.7
27.0
42.3
1934
HYDRO-ELECTRIC POWER COMMISSION
321
"A"— Continued
Hydro Municipalities as at December 31, 1933
GEORGIAN BAY
SYSTEM
Alliston
1,379
Arthur
1,037
Barrie
7,455
Beaverton
960
Beeton
584
Bradford
1,009
Brechin
P.V.
Canning-
ton
851
$ c.
$ c.
$ c.
14,199.11
15,279.30
56,509.52
66,437.67
42,184.26
40,238.97
12,063.80
$ c.
299.50
$ c.
$ c
$ c
$ c.
675 73
428.50
11,710.00
388.50
19,057.00
26,609.18
17,169.34
20,956.37
1,789.59
10,008.17
7,039.73
7,110.66
1,522.69
3,961.15
3,382.92
767.21
6,731.49
5,618.48
1,173.58
2,188.63
1,931.95
1,169.54
4,072.65
3,898.73
544.95
1,126.71
726.95
212.44
4,156.88
4,214.51
924.69
2,565.49
382.26
7,612.84
2,583.41
1,433.38
1,828.94
546.92
644.33
7,846.49
1,086.62
42,634.32
3,772.42
3,609.37
53,369.97
340.90
26,749.50
33.57
297,159.79
5,087.92
41,135.25
1,065.55
9,000.00
1,201.13
17.85
18,862.00
493.59
29,790.77
1,945.87
1,000.00
2,950.55
22.62
4,402.61
412.38
1,077.07
23,557.95
10.00
1,326.62
2,475.70
215.94
10.20
12,943.01
. 94.77
1,186.69
11.22
1,768.49
175.92
11,295.94
10,746.86
73,212.70
12,230.73
8,727.20
9,628.32
4,761.23
9,119.57
67,482.51
37,756.07
11,514.07
388,498.19
64,650.51
29,280.70
1,590.95
45,338.13
10,653.29
35,958.55
67,482.51
49,270.14
388,498.19
64,650.51
30,871.65
45,338.13
10,653.29
35,958.55
25,981.75
93.75
17,642.69
2,574.06
26,798.16
34,823.65
6,623.12
176.25
10,128.17
785.. 80
18,182.07
536.57
2,153.26
290.87
7,967.85
90.57
437.82
3.00
378.47
175.98
21.85
26,075.50
20,216.75
61,624.81
7,177.84
10,913.97
18,894.62
2,465.98
8,496.24
11,295.94
13,193.34
10,746.86
10,949.22
73,212.70
59,932.40
1,100.00
12,230.73
11,187.92
8,727.20
6,358.65
9,628.32
7,477.14
4,761.23
1,664.18
9,119.57
7,378.27
24,489.28
21,696.08
134,245.10
23,418.65
15,085.85
17,105.46
6,425.41
16,497.84
14,018 75
7,357.31
81,201.84
8,376.88
4,871.83
7,017.93
1,057.66
7,032.15
2,899.48
111,426.44
25,677.14
2,320.12
704.24
3,932.32
16,917.73
7,357.31
192,628.28
34,054.02
4,871.83
9,338.05
1,761.90
10,964.47
67,482.51
49,270.14
388,498.19
64,650.51
30,871.65
45,338.13
10,653.29
35,958.55
46.4
74.9
19.5
13.7
53.1
52.9
41.9
31.7
322
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Balance Sheets of Electrical Departments of
GEORGIAN BAY
SYSTEM— Continued
Chats-
worth
272
Chesley
1,789
Coldwater
626
Colling-
wood
5,783
Cooks-
town
P.V.
Assets
$ c.
221.00
$ c.
' ' 595 . 98
19,892.45
$ c.
275.00
$ c.
15,950.08
11,203.24
47,964.46
$ c.
60 00
Substation equipment
392 95
Distribution sustem — overhead . . .
Distribution system — underground
4,560.47
7,675.00
9,131.52
1,531.99
1,377.30
529.17
6,781.32
6,714.58
1,173.68
2,779.67
2,932.65
440.68
17,011.28
22,144.71
2,876.90
2,192.62
2,117.12
694.21
Meters
Street light equipment, regular. . . .
Street light equipment, ornamental
Miscellaneous construction expense
Steam or hydraulic plant
385.90
3,264.32
173.52
6,165.17
1,520.03
Old plant
5,503.60
Other plants not distributed
Total plant
8,605.83
2,403.79
43,925.93
15.00
10,000.00
2,652.17
265.49
14,276.52
1,544.09
4,000.00
801.92
123,315.84
100.00
27,000.00
1,743.73
399.06
16.108.45
3,005.03
374.06
4.90
3,234.69
2,277.29
896 20
17.34
Sinking fund on local debentures. .
Equity in H-E.P.C. systems
Other assets
18,843.00
7,205.13
80,932.71
2,675.43
16,900.56
75,701.59
27,827.66
233,491.34
22,702.45
Deficit
Total
16,900.56
75,701.59
27,827.66
233,491.34
22,702.45
Liabilities
4,600.09
142.95
5,030.54
3.40
1,850.60
3,630.30
466.72
6,556.37
7,285.52
1,768.70
64.00
Total liabilities
4,743.04
6,884.54
4,161.02
9,054.22
6,556.37
Reserves
For equity in H-E.P.C. systems. . .
2,277.29
2,786.38
18,843.00
13,810.48
7,205.13
6,947.36
80,932.71
40,788.04
2,675.43
5,834.73
5,063.67
Total reserves
32,653.48
14,152.49
121,720.75
8,510.16
Surplus
799.91
3,234.69
3,059.25
22,469.46
3,369.70
42,604.59
6,943.63
Local sinking fund
Operating surplus
13,694.11
6,144.45
60,111.78
692.29
Total surplus
7,093.85
36,163.57
9,514.15
102,716.37
7,635.92
Total liabilities, reserves and surplus
16,900.56
75,701.59
27,827.66
233,491.34
22,702.45
Percentage of net debt to total assets
13.2
12.1
20.2
5.9
32.7
1934
HYDRO-ELECTRIC POWER COMMISSION
323
"A"— Continued
Hydro Municipalities as at December 31, 1933
Creemore
587
Dundalk
647
Durham
1,800
Elmvale
P.V.
Elmwood
P.V.
Flesherton
491
Grand
Valley
587
Graven-
hurst
1,830
56.59
546.02
21,672.38
106.25
2,273.07
8,248.86
36.50
3,526.17
5,293.35
7,291.01
7,715.03
4,812.76
5,446.88
11,341.14
25,813.61
3,171.36
2,955.37
295.27
3,435.53
2,494.99
1,082.10
6,890.62
6,873.66
1,381.46
3,959.64
3,254.07
447.17
803.88
992 . 73
302.28
1,802.52
2,183.55
720.51
2,179.63
2,724.23
503.83
7,330.04
9,033.70
3,904.71
279.27
416.38
1,693.58
542.13
1,093.62
934.82
205 . 70
2,062.32
3,433.74
380.94
2,091.39
919.85
28,055.29
17,426.02
288 . 76
15,524.97
229.70
3,000.00
38.05
39.78
41,205.70
18,831.19
3,204.44
8,005.27
1,419.21
11,088.28
2,828.68
17,910.88
997.89
2,128.60
1,051.91
85,019.19
1,703.49
8,000.00
2,177.12
' 56.47
508.76
10.20
714.99
602.37
8.10
386.40
2,053.66
246.04
19.40
6,428.32
672.99
7,875.98
6,686.98
6,385.69
17,853.68
8,963.33
3,628.75
6,573.09
11,934.82
24,920 7?
25,218.19
69,292.97
31,713.95
12,475.01
17,811.15
28,662.37
113,634.79
24,920.72
25,218.19
69,292.97
31,713.95
12,475.01
17,811.15
28,662.37
113,634.79
534.79
1,611.99
774.06
38.05
3,243.19
119.10
1,122.31
3,236.60
455.36
2,617.46
3,716.89
66.39
2,563.49
30.56
10,815.64
4,371.58
2,146.78
812.11
4,484.60
3,691.96
2,617.46
3,783.28
2,594.05
15,187.22
6,686.98
3,195.79
6,385.69
3,914.14
17,853.68
10,294.40
8,963.33
6,646.79
2,053.66
2,740.38
3,628.75
3,652.07
6,573.09
5,220.18
11,934.82
16,984.02
725.00
9,882.77
10,299.83
28,148.08
15,610.12
4,794.04
7,280.82
11,793.27
29,643.84
5,965.21
5,562.84
22,556.81
3,763.40
4,582.54
386.40
94.57
2,983.11
8,436.51
53,152.77
7,875.98
6,925.96
8,543.41
14,103.48
8,648.47
3,763.94
5,838.54
7,774.98
12,891.17
14,106.25
36,660.29
12,411.87
5,063.51
6,747.05
14,275.05
68,803.73
24,920.72
25,218.19
69,292.97
31,713.95
12,475.01
17,811.15
28,662.37
113,634.79
11.8
4.3
8.7
16.2
22.2
26.7
11.7
14.9
324
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Balance Sheets of Electrical Departments of
GEORGIAN BAY
SYSTEM— Continued
Municipality
Hanover
3,036
Holstein
P.V
Huntsville
2,507
Kincardine
2,429
Kirkfield
Population
P.Y.
Assets
Lands and buildings
Substation equipment
Distribution system — overhead. . .
Distribution system — underground
Line transformers
Meters
Street light equipment, regular. . . .
Street light equipment, ornamental
Miscellaneous construction expense
Steam or hydraulic plant
$ c.
3,001.32
9,271.19
48,940.62
$ c.
$ c.
353.52
647.30
13,139.83
$ c.
6,389.46
2,794.20
42,159.41
$ c.
2,102.68
5,113.67
17,109.90
15,506.91
2,326.30
571.82
514.82
168.69
6,767.62
8,673.71
2,262.52
10,712.42
10,492.19
5,200.12
557.90
701.85
379.00
5,267.64
205.93
566.45
5,320.59
301.53
Old plant . ...
2,370.91
5,436.20
Other plants not distributed
Total plant
103,794.79
1,582.81
26,699.39
2,542.84
114.36
3,563.94
380.24
37,847.15
3,883.45
13,000.00
1,480.61
2,064.60
83,068.39
50.00
7,053.95
Bank and cash balance
Securities and investments
294.05
Accounts receivable
Inventories
136.07
67.87
590.42
1,243.31
936.81
Sinkinf fund on local debentures. .
Equity in H-E.P.C. systems
Other assets
45,822.14
2,093.02
30,684.78
18,529.52
111.54
1,744.11
Total assets
180,556.33
6,241.14
4,665.82
88,960.59
103,593.18
10,028.92
Deficit
1,339.48
Total
180,556.33
10,906.96
88,960.59
103,593.18
11,368.40
Liabilities
Debenture balance . .
33,987.83
54.57
225.54
4,927.71
2,393.71
3,059.92
31,103.03
1,896.96
297.79
2,572.46
Accounts payable
1,620.22
Bank overdraft
Other liabilities
544.50
Total liabilities
34,042.40
5,153.25
5,998.13
33,297.78
4,192.68
Reserves
For equity in H-E.P.C. systems. . .
For depreciation
45,822.14
36,590.63
2,093.02
1,124.18
30,684.78
12,125.08
18,529.52
15,626.77
1,744.11
2,004.07
Other reserves. .
Total reserves . .
82,412.77
3,217.20
42,809.86
34,156.29
3,748.18
Surplus
Debentures paid
53,512.17
2,536.51
18,739.83
33,096.97
3,427.54
Local sinking fund
Operating surplus.
10,588.99
21,412.77
3,042.14
Total surplus .
64,101.16
2,536.51
40,152.60
36,139.11
3,427.54
Total liabilities, reserves and surplus
180,556.33
10,906.96
88,960.59
103,593 . 18
11,368.40
Percentage of net debt to total assets
25.3
124.2
10.2
39.1
50.6
1934
HYDRO-ELECTRIC POWER COMMISSION
325
"A"— Continued
Hydro Municipalities as at December 31, 1933
Lucknow
1,082
Markdale
774
Meaford
2,707
Midland
6,808
Mildmay
694
Mount
Forest
1,821
Neustadt
465
Orange-
ville
2,785
$ c.
$ c.
$ c.
1,104.93
2,398.85
30,015.36
$ c.
19,983.57
85,096.20
93,649.38
$ c.
6,001.09
$ c.
3,725.00
686.75
22,682.88
$ c.
$ c.
2,585.07
780.80
10,503.49
1,169.00
17,009.20
9,970.79
32,266.89
4,385.00
4,717.22
1,391.17
4,151.74
3,244.99
1,314.08
7,278.23
7,317.62
3,215.81
22,972.26
36,046.39
18,712.15
1,657.05
2,129.16
502.80
6,594.59
7,294.95
2,302.55
3,624.89
2,017.85
496.41
7,922.99
11,400.36
7,532.55
2,322.02
674.93
1,987.27
5,386.19
836.82
2,127.00
1,521.48
6,243.69
2,080.65
3,486.43
849.00
3,810.95
1,097.60
3,204.99
29,824.61
1,236.22
22,750.68
1,110.39
1,255.13
936.11
35.00
56,804.50
2,812.48
16,083.05
1,780.17
281,846.14
75.00
29,000.00
19,199.98
4,127.10
11,975.92
1,190.61
945.94
49,224.67
18,729.02
8.11
"37.22
18.20
72,325.54
921.53
4,000.00
1,386.42
8.52
4,000.00
1,718.29
2,500.00
1,814.79
284.96
9,186.02
5,032.19
12,735.65
125,095.10
226.15
16,380.02
5,502.73
21,353.58
45,641.79
31,119.50
90,215.85
459,343.32
14,338.62
71,322.98
24,295.28
16,712.99
99,200.40
45,641.79
31,119.50
90,215.85
459,343.32
14,338.62
71,322.98
41,008.27
99,200.40
10,801.77
67.28
5,482.32
738.58
34,814.09
29,703.26
33,883.74
2,034.42
772.64
11,895.23
85.53
11,721.92
250.00
660.41
6,741.81
12,022.60
7,992.00
1,021.55
20.00
757.89
10,869.05
6,240.90
35,571.98
66,394.06
11,980.76
12,632.33
18,764.41
9,013.55
9,186.02
5,268.25
5,032.19
4,953.50
12,735.65
9,182.03
125,095.10
110,915.85
226.15
206.00
16,380.02
14,338.12
5,502.73
6,482.94
21,353.58
19,878.88
14,454.27
9.985.69
21,917.68
236,010.95
432.15
30,718.14
11,985.67
41,232.46
8,921.59
3,517.68
14,546.11
82,366.73
408.27
19,236.68
10,258.19
27,908.00
11,396.88
11,375.23
18,180.08
74,571.58
1,517.44
8,735.83
21,046.39
20,318.47
14,892.91
32,726.19
156,938.31
1,925.71
27,972.51
10,258.19
48,954.39
45,641.79
31,119.50
90,215.85
459,343.32
14,338.62
71,322.98
41,008.27
99,200.40
29.8
23.9
45.9
19.8
84.9
24.9
99 9
11.6
326
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Balance Sheets of Electrical Departments of
GEORGIAN BAY
SYSTEM— Continued
Municipality
Owen
Sound
12,803
Paisley
732
Penetang-
uishene
4,046
Port
Elgin
1,230
Port
Population
McNicoll
928
Assets
Lands and buildings
$ c.
25,978.31
12,919.97
106,461.46
$ c.
' 1 ,933 '. 26
11,504.45
$ c.
2,262.10
7,076.39
41,283.35
$ c.
111.25
$ c.
369 08
Substation equipment
Distribution system — overhead . . .
Distribution system — underground
Line transformers
25,301.65
7,448.38
46,603.72
56,436.43
27,532.69
1,602.53
2,930.91
1,045.51
15,661.52
13,754.34
3,503.33
5,335.48
6,039.69
2,057.10
1,322.48
Meters
2,497.83
Street light equipment, regular. . . .
Street light equipment, ornamental
Miscellaneous construction expense
Steam or hydraulic plant
Old plant
422.33
3,879.83
33,282.00
885.45
1,530.00
759.34
659 . 19
1,745.00
4,213.00
Other plants not distributed
Total plant. .
313,094.41
688.88
21,647.11
609.71
2,500.00
506.94
85,071.03
43,817.51
5,394.35
7,500.00
695 . 24
27.64
12,719.29
Bank and cash balance
78.99
Securities and investments
1,152.98
6,992.36
467.76
Accounts receivable
17,691.85
10,699.29
306.22
Inventories
11.70
Sinking fund on local debentures. .
Equity in H-E.P.C. systems
Other assets
101,536.38
5,273.82
36,078.52
1,938.03
3,328.98
Total assets
443,710.81
30,537.58
129,762.65
59,372.77
16,445.18
Deficit
Total
443,710.81
30,537.58
129,762.65
59,372.77
16,445.18
Liabilities
Debenture balance
10,091.92
17.50
15,587.71
7,335.47
2,386.80
37,995.69
4,498.92
2,070.25
Accounts payable
1.00
4,098.74
2,667.72
677.47
Bank overdraft
Other liabilities
20.00
Total liabilities
6,767.46
10,109.42
25,309.98
42,514.61
2,747.72
Reserves
For equity in H-E.P.C. systems . . .
For depreciation
101,536.38
59,025.51
5,273.82
3,623.07
36,078.52
31,117.49
1,938.03
2,184.18
3,328.98
4,101.83
Other reserves
Total reserves
160,561.89
8,896.89
67,196.01
4,122.21
7,430.81
Surplus
Debentures paid
Local sinking fund
141,000.00
5,908.08
25,412.29
4,004.31
5,229.75
Operating surplus
135,381.46
5,623.19
11,844.37
8,731.64
1,036.90
Total surplus
276,381.46
11,531.27
37,256.66
12,735.95
6,266.65
Total liabilities, reserves and surplus
443,710.81
30,537.58
129,762.65
59,372.77
16,445.18
Percentage of net debt to total assets
1.9
40.0
27.0
74.0
20.9
934
HYDRO-ELECTRIC POWER COMMISSION
327
' 'A"- Continued
Hydro Municipalities as at December 31, 1933
Port Perry
1,130
Priceville
P.V.
Ripley
451
Rosseau
251
Shelburne
1,064
Southamp-
ton
1,520
Stayner
1,042
Sunderland
P.V.
$ c.
$ c.
68.00
$ c.
$ c.
$ c.
800.00
566.60
14,735.46
$ c.
25.00
$ c.
$ c.
2 564 65
200.00
12,527.17
18,957.29
4,661.78
9,975.19
7,102.01
19,252.84
4,158.87
4,391.61
3,990.22
1,037.90
702.86
380.00
139.88
3,540.24
1,434.83
844.33
2,204.63
1,032.67
436.95
6,215.47
6,411.08
1,059.60
5,833.56
6,964.94
1,958.73
5,380.00
5,227.20
966.80
1,365.63
1,998.01
627.74
176.42
833.90
1,164.99
1,126.07
2,273.26
1,276.60
326.63
178.02
739.50
2,077.00
4,132.41
2,030.00
31,118.09
1,589.23
6,786.42
139.92
16,959.58
1,127.09
11,902.33
752.99
32,800.97
37,388.67
2,549.49
28,760.21
444 . 79
4,000.00
664.40
10,358.27
1,965.18
10,000.00
5,000.00
726.63
82.19
1,000.00
619.41
46.41
54.34
4.08
413.09
• 22.34
1,505.29
1,344.96
23.15
374.90
9.39
7,789.28
838.98
3,882.39
790.05
10,112.03
1,993 07
8,696.77
6,183.71
51,162.42
7,823.74
6,995.38
22,404.49
14,950.66
48,721.82
43,299.34
42,566.17
19,891.45
51,162.42
14,819.12
22,404.49
14,950.66
48,721.82
43,299.34
42,566.17
19,891.45
14,961.30
5.38
2,920.31
5,384.44
10,389.37
43.15
13,000.00
19.15
4,306.73
1,283.26
238.54
24,930.96
332.60
1,165.63
706.76
3,006.79
2,156.84
273.99
70.00
25.00
15,240.67
8,304.75
10,502.52
13,019.15
5,828.53
25,263.56
1,897.39
5,163.63
7,789.28
5,827.11
838.98
1,595.70
3,882.39
3,127.76
790.05
492.47
648.99
10,112.03
10,273.07
1,993.07
1,847.00
8,696.77
9,032.87
6,183.71
3,176.56
13,616.39
2,434.68
7,010.15
1,931.51
20,385.10
3,840.07
17,729.64
9,360.27
4,920.36
4,079.69
3,582.57
15,613.27
8,069.04
12,834.37
3,793.21
17,385.00
1,309.25
6,894.92
6,126.67
10,104.77
1,574 34
22,305.36
4,079.69
4,891.82
22,508.19
14,195.71
22,939.14
5,367.55
51,162.42
14,819.12
22,404.49
14,950.66
48,721.82
43,299.34
42,566.17
19,891.45
35.1
118.9
56.8
91.9
15.1
61.1
5.6
37.7
328
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Balance Sheets of Electrical Departments of
GEORGIAN BAY
SYSTEM— Continued
Municipality
Tara
491
Teeswater
805
Thornton
P.V.
Tottenham
546
Uxbridge
1,506
Population
Assets
Lands and buildings
$ c.
$ c.
$ c.
$ c.
$ c.
40 00
Substation equipment
330.31
16,987.54
358.50
8,055.08
2,657 65
Distribution system — overhead . . .
Distribution system — underground
Line transformers
Meters
Street light equipment, regular. . . .
10,999.17
2,176.95
1,719.24
430.59
6,403.82
13,388.67
4,746.02
3,315.65
1,406.90
860.41
796.76
381.95
1,117.48
2,109.02
460.17
3,875.43
4,475.05
1,259.64
Street light equipment, ornamental
1,269.05
Miscellaneous construction expense
Steam or hydraulic plant
1,907.49
300.35
1,265.68
910.15
Old plant
4,976.86
286.45
Other plants not distributed
Total plant
Bank and cash balance. .
16,595.00
1,530.50
33,670.77
558.28
3,000.00
348.96
8,743.29
396.61
13,652.38
448.48
26,606.59
Securities and investments. .
8,000.00
Accounts receivable
Inventories
289.00
61.20
323.16
987.60
24.48
1,033.14
6.12
Sinking fund on local debentures
Equity in H-E.P.C. systems
Other assets
4,661.32
6,444 . 10
1,777.80
5,592.84
8,297.67
Total assets
23,137.02
3,001.19
44,022.11
11,240.86
4,362.14
20,705.78
3,108.43
43,943.52
Deficit
Total
26,138.21
44,022.11
15,603.00
23,814.21
43,943.52
Liabilities
Debenture balance
Accounts payable
Bank overdraft
5,497.64
38.25
12,157.05
3,847.88
3,389.31
2,604.20
7,629.59
498.99
11,860.05
658 '. 19
Other liabilities
4.00
154.06
5.00
Total liabilities
5,535.89
16,008.93
5,993.51
8,282.64
12,523.24
Reserves
For equity in H-E.P.C. systems. . .
For depreciation
4,661.32
5,938.64
6,444.10
4,406.16
1,777.80
3,721.00
5,592.84
4,601.22
8,297.67
4,553.14
Other reserves. .
Total reserves
10,599.96
10,850.26
5,498.80
10,194.06
12,850.81
Surplus
Debentures paid
Local sinking fund
10,002.36
15,842.95
4,110.69
5,337.51
4,347.54
Operating surplus
1,319.97
14,221.93
Total surplus
10,002.36
17,162.92
4,110.69
5,337.51
18,569.47
Total liabilities, reserves and surplus
26,138.21
44,022.11
15,603.00
23,814.21
43,943.52
Percentage of net debt to total assets
30.0
42.6
63.3
54.8
35.1
1934
HYDRO-ELECTRIC POWER COMMISSION
329
"A"— Continued
Hydro Municipalities as at December 31, 1933
Victoria
Harbor
1,171
Walkerton
2,340
Waubau-
shene
P.V.
Wiarton
1,911
Winder-
mere
135
Wingham
1,842
Woodville
414
GEORGIAN
BAY
SYSTEM
SUMMARY
$ c
$ c.
$ c.
$ c.
$ c.
$ c.
9,163.34
4,863.91
40,474.75
$ c.
2,970.40
$ c.
110,690.15
173,392.17
8,616.56
39,551.62
6,129.60
21,291.32
9,169.96
1,146,338.42
66,437.67
1,278.18
2,252.25
366.32
10,638.64
10,475.11
2,276.74
1,556.06
1,810.39
221.79
5,554.58
5,780.34
1,950.58
2,852.40
865.05
247.26
15,635.95
14,188.17
3,371.64
2,127.54
2,116.14
217.55
378,217.38
401,981.17
132,759.04
667.12
1,984.43
370.39
5,001.65
354.57
4,930.59
14,711.99
12,320.02
275.21
103,402.25
47,993 99
5,238.00
3,981.00
2,182.50
165,592.50
13,180.43
328.50
70,164.54
4,198.07
10,088.23
1,911.68
43,559.47
2,402.59
13,489.24
10.00
119,660.36
30.00
9,000.00
1,250.88
5,671.97
9,889.34
546.85
5,000.00
895.27
2,726,804.74
68,376.93
218,145.77
514.38
16.32
1,878.86
578.52
255.78
.22.00
457.08
31.96
1,367.46
117,057.09
27,596 75
11,497 07
3,642.44
3,921.66
2,070.83
3,047.88
722.32
18,287.75
6,229.56
863,259.30
111 54
17,682.07
80,741.65
14,348.52
49,498.98
15,589.02
153,900.96
22,561.02
4,032,849.19
53,290.45
17,682.07
80,741.65
14,348.52
49,498.98
15,589.02
153,900.96
22,561.02
4,086,139.64
1,004.26
49.96
59,094.17
25.88
559.40
13.30
36,268.93
331.12
4,530.68
8,378.61
188.38
345.00
35,153.07
2,868.88
75.77
672,671 .15
144,632.18
2,234.15
444.77
23,493 67
5.00
5.00
8,526 57
1,054.22
59,125.05
572.70
36,605.05
13,442.67
37,831.99
2,944.65
849,323.57
3,642.44
3,758.26
3,921.66
2,630.78
2,070.83
2,177.94
3,047.88
2,014.94
722.32
883 . 88
189.57
18,287.75
22,444.34
6,229.56
2,077.27
863,259.30
674,284.37
2 663 56
7,400.70
6,552.44
4,248.77
5,062.82
1,795.77
40,732.09
8,306.83
1,540,207.23
5,495.74
3,905.83
2,940.60
1,131.07
60,952.43
2,631.12
943,745.38
11,497 07
3,731.41
11,158.33
6,586.45
6,700.04
350.58
14,384.45
8,678.42
741,366.39
9,227.15
15,064.16
9,527.05
7,831.11
350.58
75,336.88
11,309.54
1,696,608.84
17,682.07
80,741.65
14,348.52
49,498.98
15,589.02
153,900.96
22,561.02
4,086,139.64
7.5
77.0
4.7
78.8
90.4
28.0
18.0
26.4
330
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Balance Sheets of Electrical Departments of
EASTERN ONTARIO
SYSTEM
Municipality
Alexandria
2,340
Apple Hill
P.V.
Athens
582
Bath
350
Belleville
Population
14,059
Assets
Lands and buildings
$ c.
$ c.
169.06
$ c.
$ c.
$ c.
36,108.70
Substation equipment
2,338.65
Distribution system — overhead . . .
Distribution system — underground
Line transformers
27,957.65
2,886.41
13,951.89
5,819.73
105,110.27
8,080.79
6,909.32
2,224.20
1,288.37
1,000.21
421.12
1,757.05
2,479.53
698.90
1,011.93
676.87
554.37
23,330.54
Meters
55,180.56
Street light equipment, regular. . . .
Street light equipment, ornamental
Miscellaneous construction expense
Steam or hydraulic plant
17,220.75
5,122.65
210.33
1,011.61
727.38
5,601.97
Old plant
4,466.89
709.55
Other plants not distributed. .....
Total plant
54,761.50
2,611.41
7,000.00
1,876.12
6,685.05
282.51
19,898.98
1,152.51
8,790.28
11.76
244,891.44
Bank and cash balance
17,671.22
Securities and investments
5,000.00
Accounts receivable
143.53
2,069.44
666.78
15,601.29
Inventories
7,079.79
Sinking fund on local debentures. .
Equity in H-E.P.C. systems
Other assets
17,415.16
1,689.16
2,458.42
418.12
59,864.19
Total assets
83,664.19
8,800.25
323.54
25,579.35
9,886.94
350,107.93
Deficit
Total
83,664.19
9,123.79
25,579.35
9,886.94
350,107.93
Liabilities
Debenture balance
19,798.16
3,571.45
3,348.68
106.37
11,759.10
7,284.91
1,605.84
52,000.00
Accounts payable
Bank overdraft
Other liabilities. .
466.23
22.00
5,443.34
Total liabilities
23,835.84
3,455.05
11,759.10
8,912.75
57,443.34
Reserves
For equity in H-E.P.C. systems. . .
For depreciation
17,415.16
10,513.76
1,689.16
1,328.26
2,458.42
1,952.75
418.12
322.00
59,864.19
20,090.75
Other reserves
1,177.47
Total reserves
27,928.92
3,017.42
4,411.17
740.12
81,132.41
Surplus
Debentures paid
28,335.68
2,651.32
2,240 90
215.09
124,000.00
Local sinking fund . .
Operating surplus
3,563.75
7,168.18
18.98
87,532.18
Total surplus
31,899.43
2,651.32
9,409.08
234.07
211,532.18
Total liabilities, reserves and surplus
83,664.19
9,123.79
25,579.35
9,886.94
350,107.93
Percentage of net debt to total assets
35.9
48.6
50.9
95.2
19.8
934
HYDRO-ELECTRIC POWER COMMISSION
33
4 *A"— Continued
Hydro Municipalities as at December 31, 1933
Bloomfield
614
Bowman-
ville
3,641
Brighton
1,413
Brockville
9,615
Cardinal
1,305
Carleton
Place
4,272
Chesterville
950
$ c.
$ c.
$ c.
$ c.
45,295.14
1,000.87
83,857.03
$ c.
$ c.
6,255.32
2,471.63
41,145.03
$ c.
250.00
410.00
11,144.26
43,954.11
14,379.75
10,811.54
7,946.71
2,230.77
2,677.82
908 . 20
7,599.91
17,014.21
2,860.10
3,965.45
6,449 . 20
821.98
35,877.33
42,945.18
20,434.12
2,580.91
2,214.16
385.27
10,331.16
16,599.67
6,758.16
3,245.64
4,112.97
526.97
1,403.42
2,406.53
236.73
3,044.90
54,961.03
4,821.76
759.18
3,580.79
658.68
3,474.80
5,293.19
18,774.47
73,834.86
11,528.65
25,853.11
25.00
292,237.36
783.90
135,000.00
9,682.82
2,385.49
20,225.86
1,183.57
92,434.95
4,319.40
19,000.00
5,200.34
892.06
16,740.97
585.95
9,000.00
235.33
4,684.85
3,046.76
4,915.73
4,194.51
39.00
723.03
608 . 79
2,562.61
11,113.91
3,884.81
90,546.25
1,431.50
40,058.83
17,050.69
21,572.41
104,209.03
38,873.16
530,635.82
22,879.93
161,905.58
44,709.43
21,572.41
104,209.03
38,873.16
530,635.82
22,879.93
161,905.58
44,709.43
7,202.16
66,486.12
22,558.84
5.21
2,687.69
78.00
13,569.91
179.43
43,641.56
1,124.18
979.35
13,877.20
5,898.12
47.00
5.40
4.89
12.00
560.53
718.73
8,198.40
67,046.65
25,329.74
19,822.32
13,749.34
44,360.29
1,129.58
2,562.61
3,970.96
11,113.91
3,261.50
3,884.81
1,694.13
90,546.25
73,525.48
6,497.60
1,431.50
982.00
40,058.83
10,431.10
1,500.00
17,050.69
7,559.10
6,533.57
14,375.41
5,578.94
170,569.33
2,413.50
51,989.93
24,609.79
3,997.84
4,513.88
2,441.16
226,657.54
1,430.09
22,358.44
5,375.82
2,842.60
18,273.09
5,523.32
113,586.63
5,287.00
43,196.92
13,594.24
6,840.44
22,786.97
7,964.48
340,244.17
6,717.09
65,555.36
18,970.06
21,572.41
104,209.03
38,873.16
530,635.82
22,879.93
161,905.58
44,709.43
43.1
72.0
72.4
4.5
64.1
36.4
4.1
332
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Balance Sheets of Electrical Departments of
EASTERN ONTARIO
SYSTEM— Continued
Municipality
Cobourg
5,619
Colborne
977
Deseronto
1,418
Finch
383
Hastings
707
Population
Assets
Lands and buildings
$ c.
$ c.
$ c.
$ c.
$ c.
Substation equipment
161.18
9,700.34
Distribution system — overhead . . .
Distribution system — underground
Line transformers
Meters
Street light equipment, regular. . . .
Street light equipment, ornamental
Miscellaneous construction expense
Steam or hydraulic plant
62,880.91
6,037.64
7,414.99
14,011.23
15,854.62
22,307.76
8,391.51
670.66
1,390.75
1,321.40
1,442.62
4,771.27
432.60
1,393.35
1,728.20
435.62
1,771.80
2,901.40
1,160.09
4,574.24
2,463.34
305.94
23.24
716.28
Old plant
1,733.13
Other plants not distributed
Total plant
114,009.04
17,960.58
11,883.79
1,956.52
16,813.95
3,436.29
10,995.40
108.70
3,000.00
121.29
22,293.93
Bank and cash balance
586.86
Securities and investments
5,000.00
Accounts receivable
Inventories
5,180.48
3,834.53
156.91
538.05
691.22
721.46
554.44
Sinking fund on local debentures. .
Equity in H-E.P.C. systems
Other assets
8,067.27
337.09
1,951.46
1,781.86
788.72
Total assets
149,051.90
14,872.36
23,614.38
16,007.25
29,223.95
Deficit
Total
149,051.90
14,872.36
23,614.38
16,007.25
29,223.95
Liabilities
Debenture balance
102,702.35
4,884.99
12,194.59
45.56
11,847.71
468.54
5,672.68
707.11
19,762.33
Accounts payable
13.80
Bank overdraft
Other liabilities
3,462.03
196.24
192.12
30.00
Total liabilities
111,049.37
12,436.39
12,508.37
6,379.79
19,806.13
Reserves
For equity in H-E.P.C. systems. . .
For depreciation
8,067.27
3,833.12
337.09
188.00
1,951.46
920.92
1,781.86
1,138.00
788.72
1,011.60
Other reserves. .
Total reserves
11,900.39
525.09
2,872.38
2,919.86
1,800.32
Surplus
Debentures paid
3,291.15
3,152.29
1,327.32
1,237.67
Local sinking fund . . .
Operating surplus
22,810.99
1,910.88
5,081.34
5,380.28
6,379.83
Total surplus
26,102.14
1,910.88
8,233.63
6,707.60
7,617.50
Total liabilities, reserves and surplus
149,051.90
14,872.36
23,614.38
16,007.25
29,223.95
Percentage of net debt to total assets
78.8
85.5
57.7
44.8
69.6
1934
HYDRO-ELECTRIC POWER COMMISSION
333
"A"— Continued
Hydro Municipalities as at December 31, 1933
Havelock
1,096
Kemptville
1,227
Kingston
23,260
Lakefield
1,303
Lanark
636
Lancaster
601
Lindsay
7,109
$ c.
$ c.
$ c.
184,945.77
45,599.79
165,930.10
149,557.13
58,020.14
99,915.93
71,262.59
$ c.
3,137.97
$ c.
$ c.
$ c.
10,556.68
572 90
3,176.56
19,583.50
19,755.54
21,813.53
6,201.44
6,402.26
71,574.10
2,259.82
5,387.88
1,842.33
5,888.74
6,490.65
1,063.16
5,101.95
7,070.99
1,876.16
1,134.89
1,796.99
682.38
962.35
1,433.52
650.65
20,920.49
30,341.01
10,291.48
4,409.17
6,067.28
46,345.74
3,815.70
330.38
1,068.55
1,608.54
2,420.45
15,890.14
3,445.25
36,476.05
2,789.27
7,000.00
39,265.37
760.85
20,000.00
3,116.38
998.53
837,467.33
65,301.65
172,175.00
36,132.75
9,806.07
32,697.13
1,000.00
46,261.55
479.65
10,000.00
1,270.74
10,146.08
711.41
1,982.05
203.48
10,517.33
357.04
148,468.86
8,431.77
46,500.00
262.62
452.20
4,918.05
424.76
5,666.80
9,967.75
4,814.31
9.74
3,115.98
4,203 . 18
34,998.34
52,194.74
74,108.88
1,154,579.93
62,835.99
16,159.00
15,529.75
6,261.95
243,741.78
52,194.74
74,108.88
1,154,579.93
62,835.99
16,159.00
21,791.70
243,741.78
16,437.62
63.08
18,271.25
2,208.15
104,430.01
6,361.67
25,935.95
700.00
3,433.99
24.35
3,297.41
5,129.50
108,275.79
19.56
640.96
360.96
73.50
1,753.18
16,500.70
20,479.40
111,432.64
26,996.91
3,458.34
8,500.41
110,048.53
9,967.75
6,873.22
9,728.63
1,763.25
2,415.10
7,112.47
127,490.12
161,795.63
16,765.26
12,779.27
16,840.97
289,285.75
14,542.94
4,879.23
6,618.28
51,763.60
16,462.38
6,728.75
207,469.99
32,697.13
513,694.42
7,564.05
4,127.48
6,673.01
21,724.21
6,452.39
30,059.76
13,732.09
3,693.95
60,205.44
22,914.77
36,788.51
753,861.54
21,296.14
7,821.43
6,673.01
81,929.65
52,194.74
74,108.88
1,154,579.93
62,835.99
16,159.00
21,791.70
243,741.78
35.5
31.9
7.0
46.5
26.5
75.0
52.7
334
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Balance Sheets of Electrical Departments of
EASTERN ONTARIO
SYSTEM— Continued
Municipality
Population
Madoc
1,059
Marmora
924
Martintown
P.V.
Maxville
785
Assets
Lands and buildings
Substation equipment
$ c.
100.00
$ c.
$ c.
126.15
$ c.
407 79
Distribution system — overhead. . . .
Distribution system — underground
Line transformers
9,680.27
12,591.18
2,709.88
11,463.57
2,351.64
4,786.31
1,500.00
2,378.99
3,395.91
1,088.59
690.33
871.51
335.26
1,540.96
Meters
Street light equipment, regular. . . .
Street light equipment, ornamental
Miscellaneous construction expense
Steam or hydraulic plant
2,465.30
1,605.64
225.89
2,000.91
653.27
2,402.45
Old plant
573.62
Other plants not distributed
Total plant
18,644.11
2,485.58
22,029.20
4,321.14
657.33
588.08
5,386.40
965 . 74
1,000.00
248.46
19,885.71
601.47
Securities and investments
Accounts receivable
Inventories
421.49
224.46
Sinking fund on local debentures. . .
Equity in H-E.P.C. systems
Other assets
2,479.40
2,136.48
1,082.90
5,041.29
Total assets
24,030.58
29,732.23
8,683.50
25,752.93
Deficit
Total
24,030.58
29,732.23
8,683.50
25,752.93
Liabilities
Debenture balance
Accounts payable
963.20
51.00
7,735.98
4.18
1,961.14
7,608.74
1.37
Bank overdraft . .
Other liabilities
10.00
80.00
Total liabilities
1,014.20
7,750.16
1,961.14
7,690.11
Reserves
For equity in H-E.P.C. systems. . .
For depreciation
2,479.40
921.05
2,136.48
4,058.21
1,082.90
1,183.37
5,041.29
3,701.66
Other reserves
Total reserves .
3,400.45
6,194.69
2,266.27
8,742.95
Surplus
Debentures paid . .
13,036.80
9,930.13
4,038.86
8,391.26
Local sinking fund. .
Operating surplus
6,579.13
5,857.25
417.23
928.61
Total surplus
19,615.93
15,787.38
4,456.09
9,319.87
Total liabilities, reserves and surplus
24,030.58
29,732.23
8,683.50
25,752.93
Percentage of net debt to total assets
4.7
28.1
25.8
37.1
934
HYDRO-ELECTRIC POWER COMMISSION
335
"A"— Continued
Hydro Municipalities as at December 31, 1933
Napanee
3,014
Norwood
727
Omemee
498
Oshawa
23,002
Ottawa
130,672
Perth
3,994
Peterborough
22,809
$ c.
2,173.32
$ c.
$ c.
$ c.
56,776.03
$ c.
337,378.21
700,669.39
709,461.28
172,744.02
303,083.73
276,306.34
117,317.59
$ c.
6,851.01
3,932.82
46,843.70
$ c.
75,202.75
457.53
23,152.45
360.32
10,880.65
98,652.41
39,244.37
183,835.78
210,098.39
8,356.22
16,394.23
3,814.09
4,609.18
4,822.00
1,848.52
2,668.47
2,434.79
667.86
40,454.32
97,743.58
15,669.64
22,413.35
20,967.92
3,939.32
95,759.24
93,552.08
53,728.00
2,787.40
3,939.32
1,540.92
6,342.36
33,115.49
5,011.75
53,652.16
2,447.51
8,831.65
23,606.94
29,771.74
72,769.63
1,934.74
41,276.51
3,781.32
8,000.00
171.77
18,553.01
2,224.49
409,653.36
250.00
2,650,076.05
2,127.29
38,000.00
99,557.41
22,198.34
682,182.51
52,211 78
133,566.81
5,472.56
35,000.00
4,161.21
7,663.13
710,416.77
330.00
4,910.96
5,065.45
163.22
57,831.30
8,574.22
29,743.35
5,053.11
225,737 16
14,478.29
2,711.38
186,135.35
304.52
34,151.00
328.15
117,464.27
99,159.07
55,940.98
20,940 7?
662,748.75
3,546,353.38
220,342.86
1,088,744.66
99,159.07
55,940.98
20,940.72
662,748.75
3,546,353.38
220,342.86
1,088,744.66
35,031 54
27,760.97
583.21
4,003.70
249,672.23
24,200.87
9,831.79
18,929.21
923,627.34
94,965.53
2,895.07
55,526.99
268.59
527,920.00
28,249 53
4,061 57
532.02
326.30
45.00
1,899.59
80.00
35,563.56
28,670.48
4,048 . 70
302,634.10
1,021,487.94
57,695.17
560,311.10
14,478.29
2,711.38
9,011.80
186,135.35
37,436.92
17,405.24
52,211.78
930,274.58
164,586.88
34,151.00
34,625.03
117,464.27
3,091.42
2,983.35
6,047.88
94,929.86
9,400 . 20
20,553.06
11,723.18
6,047.88
240,977.51
1,147,073.24
68,776.03
221,794.33
34,968.46
.9,339.03
7,996.30
60,327.77
56,372.66
682,182.51
639,237.03
52,873.01
225,737.16
8,073.99
6,208.29
2,847.84
58,809.37
40,998.65
80,902.07
43,042.45
15,547.32
10,844.14
119,137.14
1,377,792.20
93,871.66
306,639.23
99,159.07
55,940.98
20,940.72
662,748.75
3,546,353.38
220,342.86
1,088,744.66
42.0
53.9
21.8
63.5
29.2
31.0
44.9
336
TWENTY-SIXTH ANNUAL REPORT OB THE
No. 26
STATEMENT
Balance Sheets of Electrical Departments of
EASTERN ONTARIO
SYSTEM— Continued
Alunicipality
Picton
3,217
Port Hope
4,626
Prescott
2,952
Richmond
381
Russell
Population
P.V.
Assets
Lands and buildings
$ c.
7,182.49
2,004.66
39,652.20
$ c.
4,050.00
$ c.
2,761.54
$ c.
$ c.
Substation equipment
Distribution system — overhead. . .
Distribution system — underground
Line transformers
47,651.69
38,915.28
6,127.37
7,735.81
12,624.33
16,740.47
4,131.66
11,598.21
19,384.64
2,613.82
13,303.50
18,431.61
2,006.66
769.40
1,136.31
173.98
1,382.48
Meters
1,458.78
Street light equipment, regular . . .
Street light equipment, ornamental
Miscellaneous construction expense
Steam or hydraulic plant
499.49
2,621.36
828.2i
1,089.63
612.67
1,199.88
Old plant
3,105.28
11,808.35
Other plants not distributed
Total plant
88,062.45
50.00
14,000.00
5,104.68
3,842.99
86,126.64
1,184.05
88,316.57
1,031.66
3,000.00
1,701.75
8,819.73
323.76
12,276.44
Bank and cash balance
1,680.80
Securities and investments
Accounts receivable
3,014 20
1,060.76
976.63
Inventories
Sinking fund on local debentures. .
Equity in H-E.P.C. systems
Other assets
20,429.65
997 . 29
17,960.58
25,550.45
106.00
894.27
2,863.57
Total assets
132,487.06
109,346.23
1,046.56
119,706.43
10,037.76
17,797.44
Deficit
Total
132,487.06
110,392.79
119,706.43
10,037.76
17,797.44
Liabilities
Debenture balance
23,863.83
4,969.50
5,504.02
104.27
7,211.90
Accounts payable . . .
3,279.09
1,562.86
978.00
908 . 69
251.23
Bank overdraft ....
Other liabilities. .
3 T 110.77
204.51
25.50
Total liabilities
5,819.95
31,944.10
1,113.20
5,633.79
7,463.13
Reserves
For equity in H-E.P.C. systems . . .
For depreciation ....
20,429.65
11,773.85
1,458.68
17,960.58
5,351.94
25,550.45
30,397.84
894.27
850.87
2,863.57
1,493.98
Other reserves. . .
Total reserves
33,662.18
23,312.52
55,948.29
1,745.14
4,357.55
Surplus
Debentures paid
5,730.32
55,136.17
23,979.34
995.98
2,788.10
Local sinking fund .
Operating surplus
87,274.61
38,665.60
1,662.85
3,188.66
Total surplus. . .
93,004.93
55,136.17
62,644.94
2,658.83
5,976.76
Total liabilities, reserves and surplus
132,487 06
110,392.79
119,706.43
10,037.76
17,797.44
Percentage of net debt to total assets
5 1
34.9
1.2
61.6
50.0
1934
HYDRO-ELECTRIC POWER COMMISSION
337
"A"— Continued
Hydro Municipalities as at December 31, 1933
Smiths Falls
7,501
Stirling
865
Trenton
6,331
Tweed
1,247
Warkworth
P.V.
Wellington
900
West port
733
$ c.
19,928.85
$ c.
8,410.00
7,042.12
5,007.22
$ c.
5,114.41
23,080.03
87,820.66
$ c.
$ c.
$ c.
200.00
499.80
14,660.44
$ c.
4,745.66
86,143.93
10,186.86
5,494.98
7,155.76
24,946.41
32,399.24
9,295.13
3,681.12
4,856.49
1,054.48
20,622.75
25,913.81
13,556.84
3,002.41
4,777.47
1,035.28
684.66
1,510.80
309.88
3,703.50
5,168.68
1,131.40
1,001.23
1,353.44
526.70
6,631.95
38,001.49
1,097.22
3,141.03
345.31
610.69
774.55
1,335.26
21,513.48
3,618.02
2,477.92
1,713.00
243,606.14
5,131.37
42,000.00
31,148.65
5,231.59
4,762.73
1,058.50
1,090.28
179,249.53
11,769.63
19,347.33
1,450.81
12,229.03
416.85
2,500.00
321.22
28,616.29
10.00
5,000.00
560.52
13,085.39
"3,000.00
4,014.82
721.28
7,688.95
6,300.75
570.00
1.197.71
653.28
52,428.70
3,026.08
50.00
15,465.69
2,472.03
1,484.82
3,949.61
949.46
347,902.31
46,367.83
220,474.55
25,037.88
16,951.92
38,136.42
17,688.13
347,902.31
46,367.83
220,474.55
25,037.88
16,951.92
38,136.42
17,688.13
69,513.40
154,510.02
13,061.29
597.09
9,401.11
11,068.35
739.08
1,352.82
2.25
14,115.96
1.62
58.60
33
24.00
2,638.89
214.69
69,513.73
25.62
157,148.91
13,873.07
9,401.11
13,162.50
14,174.56
52,428.70
62,565.37
250.00
3,026.08
8,672.11
15,465.69
6,748.00
661.84
2,472.03
1,956.13
1,484.82
1,201.32
3,949.61
5,482.78
949.46
244.56
115,244.07
11,698.19
22,875.53
4,428.16
2,686.14
9,432.39
1,194.02
128,111.60
10,000.00
10,489.98
5,938.71
1,598.89
5,931.65
884.04
35,032.91
24,644.02
29,960.13
797.94
3,265.78
9,609.88
1,435.51
163,144.51
34,644.02
40,450.11
6,736.65
4,864.67
15,541.53
2,319.55
347,902.31
46,367.83
220,474.55
25,037.88
16,951.92
38,136.42
17,688.13
23.5
.06 .
76.7
61.5
60.8
38.5
85.2
338
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Balance Sheets of Electrical Departments of
EASTERN ONTARIO
SYSTEM— Concluded
Municipality
Whitby
5,294
Williamsburg
P.V.
Winchester
963
EASTERN
ONTARIO
Population
SYSTEM
SUMMARY
Assets
Lands and buildings
$ c
6,394. It
34,200.41
44,799.06
$ c
$ c
299 . 85
$ c.
819,667.51
931,784.52
2,453,623.17
322 301 15
Substation equipment
Distribution system — overhead. . .
Distribution system — underground
2,510. 5£
9,529.85
Line transformers
Meters
Street light equipment, regular. . .
Street light equipment, ornamental
10,993.72
14,537.89
4,567.02
1,749.87
1,926.37
152.11
2,436.78
4,904.37
719.87
813,528.08
1,022,036.39
396,512.94
Miscellaneous construction expense
Steam or hydraulic plant
5,815.00
50.85
616.57
234,934.74
92,962.52
154,162.80
Old plant
1,340.13
1,100.00
Other plants not distributed
Total plant
122,647.49
458.47
6,389.78
1,277.70
4,500.00
1,620.36
19,607.29
1,013.44
7,000.00
727.44
7,241 513 82
Bank and cash balance
198 560 93
Securities and investments
609,077 11
Accounts receivable
4,452.64
141.87
329 385 52
Inventories
97,440.69
940,616.80
923,102.87
2,795.70
Sinking fund on local debentures. .
Equity in H-E.P.C. systems
Other assets
20,245.70
2,473.15
10,830.56
Total assets
147,946.17
16,260.99
39,178.73
10,342,493.44
Deficit
7,632.05
Total
147,946.17
16,260.99
39,178.73
10,350,125.49
Liabilities
Debenture balance
36,673.08
45.20
210.01
604.59
6,101.67
96.72
2,874,081.77
Accounts payable
200,877.92
Bank overdraft
28,353.41
Other liabilities
768.97
477.65
5.00
44,409.50
Total liabilities
37,487.25
1,292.25
6,203.39
3,147,722.60
Reserves
For equity in H-E.P.C. systems. . .
For depreciation
20,245.70
16,34261
2,473.15
1,788.02
10,830.56
6,712.24
923,102.87
1,601,734.88
Other reserves
367,716.89
Total reserves
36,588.31
4,261.17
17,542.80
2,892,554.64
Surplus
Debentures paid
39,939.42
2,539.99
4,548.33
1,259,862.86
Local sinking fund
Operating surplus
33,931.19
8,167.58
10,884.21
2,109,368.59
Total surplus
73,870.61
10,707.57
15,432.54
4,309,848.25
Total liabilities, reserves and surplus
147,946.17
16,260.99
39,178.73
10,350,125.49
Percentage of net debt to total assets
29.3
9.4
21.8
26.0
1934
HYDRO-ELFXTRIC POWER COMMISSION
339
"A"— Concluded
Hydro Municipalities as at December 31, 1933
THUNDER BAY
SYSTEM
Fort William
25,188
Nipigon
Port Arthur
19,749
THUNDER
BAY
SYSTEM
SUMMARY
ALL
SYSTEMS
GRAND
SUMMARY
$ c.
48,927.62
123,548.71
$ c.
215.03
$ c.
382,856.81
240,367.20
443,500.81
$ c.
431,999.46
363,915.91
597,308.77
$ c.
10,186,471.28
22,306,800.94
140,613.54
13,194.42
21,152,681.20
5,945,225.61
62,413.22
61,540.24
29,781.46
2,566.91
2,344.61
606 . 24
67,012.85
90,004.85
77,096.02
131,992.98
153,889.70
107,483.72
9,478,605.14
8,514,165.03
2,381,599.40
1,458,443.68
6,038.64
93.53
32,543.86
348,777.37
38,676.03
348,777.37
293,762.46
4,040,859.74
502,978.62
293,762.46
5,016,755.92
200,000.00
766,625.89
1,473.68
6,000.00
19,020.74
2,691.86
1,682,159.77
70,484.76
594,994.87
88,750.99
21,592.86
240,087.76
821,761.42
1,088.37
2,467,806.40
74,650.30
600,994.87
118,463.61
24,076.31
417,992.81
1,062,986.47
1,088.37
91,184,586.56
1,696,489.24
2,163,785.20
28,951.61
2,483.45
761.01
3,746,910.92
1,226,043.30
177,905.05
9,386,176.58
239,785.83
1,439.22
26,045,679.00
253,581.84
1,223,225.51
23,912.83
3,520,920.80
4,768,059.14
135,703,252.64
75,416.85
1,223,225.51
23,912.83
3,520,920.80
4,768,059.14
135,778,669.49
415,500.00
25,719.16
6,876.12
803.55
361,165.28
143,310.57
783,541.40
169,833 . 28
42,606,145.29
3,320,485.45
206,398.00
10,332.83
10,332.83
3,787,725.14
451,551.99
7,679.67
504,475.85
963,707.51
49,920,753.88
239,785.83
69,227.30
11,402.34
1,439.22
2,978.00
821,761.42
397,387.59
76,441.73
1,062,986.47
469,592.89
87,844.07
26,045,679.00
16,075,959.28
2,048,081.84
320,415.47
4,417.22
1,295,590.74
1,620,423.43
44,169,720.12
252,150.00
177,905.05
3,123.88
280,934.72
240,087.76
1,199,831.73
536,208.60
417,992.81
1,229,726.79
17,651,367.71
9,386,176.58
21,203.00
8,692.06
14,650,651.20
451,258.05
11,815.94
1,720,854.21
2,183,928.20
41,688,195.49
1,223,225.51
23,912.83
3,520,920.80
4,768,059.14
135,778,669.49
34.0
34.2
18.7
14.7
39.5
340
TWENTY-SIXTH ANNUAL REPORT OF THE No. 26
STATEMENT
Detailed Operating Reports of Electrical Departments of
NIAGARA
SYSTEM
Municipality
Acton
1,895
Agincourt
P.V.
Ailsa
Craig
464
Alvinston
690
Amherst-
Population
burg
3,086
Earnings
Domestic service
$ c.
9,980.21
3,956.25
16,484.40
663.43
1,824.00
$ c.
5,107.67
1,136.42
1,289.18
$ c.
2,631.21
1,469.89
1,020.69
$ c.
3,991.86
2,354.46
174.71
265.85
1,854.00
$ c.
19,006.20
Commercial light service
6,657.90
Commercial power service
5,375.25
Municipal power
750.04
620.50
2,270.22
Merchandise
Miscellaneous
329.11
89.61
302.49
96.30
675.97
Total earnings
33,237.40
8,372.92
6,044.78
8,737.18
33,985.54
Expenses
Power purchased
26,866.21
5,342.11
4,525.23
6,549.36
21,591.10
Substation operation
Substation maintenance
Distribution system, operation and
maintenance
2,361.66
160.25
217.85
423.59
254.61
42.24
2,350.28
Line transformer maintenance
20.64
Meter maintenance
169.51
386.09
Consumers' premises expenses
34.04
Street lighting, operation and main-
tenance
349.80
145.87
97.40
85.37
529.99
Promotion of business
Billing and collecting
General office, salaries and expenses. .
Undistributed expenses
Truck operation and maintenance. . .
Interest
690.60
444.97
233.58
140.29
32.60
649.58
1,324.00
181.24
133.09
34.79
251.00
215.88
26.75
2,303.87
322.40
981.51
161.84
286.08
260.06
566.40
354.00
742 . 73
1,048.37
597.00
1,456.46
Sinking fund and principal payments
on debentures
1,304.96
Depreciation
451.00
1,846.00
Total operating costs and fixed
charges
33,471.39
7,414.43
5,846.87
9,558.70
33,253.86
Net surplus
958.49
197.91
732.68
Net loss
233.99
821.52
Number of Consumers
Domestic service
Commercial light service
Power service
482
89
16
143
23
3
130
38
2
151
52
2
586
124
15
Total
587
169
170
205
725
1934
HYDRO-ELECTRIC POWER COMMISSION
341
"B"
Hydro Municipalities for Year Ended December 31, 1933
Ancaster
Twp.
Arkona
416
Aylmer
1,989
Ayr
768
Baden
P.V.
Beachville
P.V.
Belle River
746
Blenheim
1,690
$ c.
8,977.54
1,788.77
550.38
292.14
$ c.
2,643.74
1,649.92
833 . 62
$ c
10,877.65
6,877.10
3,056.22
901.31
2,320.00
$ c
5,126.69
1,852.48
161.85
$ c.
3,596.36
1,487.40
4,821.19
$ c.
3,018.55
662.16
9,134.26
.$ c
3,411.84
1,556.07
432.15
989.07
693.00
$ c
8,520.56
6,206.73
3,506.91
1,533.93
1,135.00
960 . 00
1,028.00
650.00
517.00
2,500.00
38
1,113.27
15.35
86.31
303 . 60
244.79
162.66
12,743.83
6,087.66
25,145.55
8,184.37
10,641.26
13,635.57
7,326.92
22,430.79
7,961.94
4,013.87
15,973.03
5,664.40
8,521.58
14,486.13
4,459.87
13,304.73
1,136.55
68.32
131.54
"2,584.85
28.20
211.86
535.05
260.99
55.64
38.54
102.02
457.55
35.70
34.80
798.77
135.09
247.95
17.64
818.80
161.70
74 45
275.28
78.82
174.44
104.34
122.20
383.81
18.44
206.25
88.70
663 . 29
1,218.10
144.64
430.86
57.60
27.00
427.32
54.61
23.20
271.71
171.57
25.68
295.86
317.06
26.38
934.41
1,540.36
1,127.42
378.57
544.61
291.10
844.00
626.95
563.21
322.00
1,228.83
1,280.35
1,408.00
365.81
349 . 60
535.00
115.60
209.66
370.00
141.30
223.30
630.00
350.65
390.39
635.00
592.31
476.84
1,383.00
12,796.53
6,026.97
25,016.43
8,061.78
10,157.40
16,250.23
7,125.46
20,352.19
60.69
129.12
122.59
483.86
201.46
2,078 60
52.70
2,614.66
268
37
5
96
36
633
133
13
208
45
3
133
35
3
133
20
4
207
46
4
490
126
10
310
132
779
256
171
157
257
626
342
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Detailed Operating Reports of Electrical Departments of
NIAGARA
SYSTEM— Continued
Municipality
Blyth
602
Bolton
593
Bothwell
646
Brampton
5,413
Brantford
Population
30,724
Earnings
Domestic service
$ c.
3,893.93
1,821.29
1,184.15
$ c.
3,426.17
967 . 73
2,327.48
$ c.
2,710.60
1,259.10
618.20
145.94
1,293.00
$ c.
36,818.92
16,148.10
15,162.91
2,458.88
5,426.50
$ c
184,129.33
62,992.72
163,495 28
Commercial light service
Commercial power service
Municipal power
21,488.11
Street lighting
1,300.00
1,113.99
34,414.16
Merchandise
Miscellaneous
10.07
9.70
615.39
1,329.01
3,924.88
Total earnings
8,209.44
7,845.07
6,642.23
77,344.32
470,444.48
Expenses
Power purchased
4,895.80
5,020.91
4,653.08
63,640.64
114.86
317,694.31
Substation operation
7,722.48
Substation maintenance
574.83
Distribution system, operation and
maintenance
154.62
288.20
104.55
2,916.26
95.95
648.71
14,197.85
Line transformer maintenance
219.06
Meter maintenance
99.95
4,833.18
Consumers' premises expenses
65
242 . 64
414.50
Street lighting, operation and main-
tenance
81.90
189.10
779.03
4,528.75
Promotion of business
769.78
Billing and collecting
240 . 68
252.10
15.00
1,614.35
973.30
775.93
240.73
731.77
3,056.52
4,267.00
91.26
9,293.44
General office, salaries and expenses. .
Undistributed expenses
278.29
419.50
9,594.42
3,935.12
Truck operation and maintenance. . .
2,363.12
I nterest
544.24
986 87
433 . 00
332.87
536.14
544 . 00
202.30
170.30
531.00
27,940.74
Sinking fund and principal payments
on debentures
50,548.93
Depreciation . . .
22,601.00
Other reserves
2,000.00
Total operating costs and fixed
charges
7,374.67
7,384.91
6,458.06
79,946.31
479,231.51
Net surplus
834.77
460.16
184.17
Net loss
2,601.99
8,787.03
Number of Consumers
Domestic service
Commercial light service
158
55
5
162
43
9
169
48
5
1,369
232
54
7,384
1,124
Power service . .
229
Total
218
214
222
1,655
8,737
1934
HYDRO-ELECTRIC POWER COMMISSION
343
"B"— Continued
Hydro Municipalities for Year Ended December 31, 1933
Brantford
Twp.
Bridgeport
P.V.
Brigden
P.V.
Brussels
770
Burford
P.V.
Burgess-
ville
P.V.
Caledonia
1,400
Campbell-
ville
P.V.
$ c
18,445.68
3,947.57
3,972.99
$ c
3,714.20
1,049.03
259.09
$ c
2,306.85
1,754.03
1,026.74
$ c
5,318.84
2,803.16
749.06
$ c
4,240.32
944 . 20
1,532.87
$ c
1,254.32
581.80
286.05
$ c
5,314.46
3,877.51
2,303.00
$ c
1,317.96
488.67
4,250.50
580.00
745.00
1,284.00
737.04
312.00
1,546.98
456.00
705 . 23
101.35
94.27
235.01
102.76
57.72
31,321.97
5,602.32
5,933.97
10,249.33
7,689.44
2,434.17
13,144.71
2,320.35
17,753.55
3,643.91
4,236.29
5,919.99
4,794.58
2,220.69
8,346.97
1,570.04
1,453.89
125.31
45.35
20.17
156.17
. 472.47
323.02
96.29
143.76
1,391.15
21.50
79.46
67.92
366.43
5.51
81.19
951.59
105.55
45.60
63.85
122.16
62.03
29.07
280.15
39.17
1,924.54
319.01
71.22
21.50
221.57
104.21
25.00
408 . 85
125.41
22.66
112.13
5.63
17.25
476.62
210.57
84.60
1,625.98
58.43
640.34
108.63
1,581.82
3,211.39
611.05
66.17
270.19
345.00
782.14
975.14
563.00
37.30
363.91
463.00
62.72
254.20
200.00
85.41
121.25
240.07
770.00
231.03
257 20
2,474.00
499.00
112.00
31,632.48
5,432.98
5,810.26
9,325.79
6,455.22
3,130.86
12,022.74
2,385.99
169.34
123.71
923.54
1,234.22
1,121.97
310.51
696 . 69
65 64
751
45
5
110
19
4
108
43
5
221
66
2
191
32
4
54
21
2
326
86
8
40
8
801
133
156
289
227
77
420
48
344
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Detailed Operating Reports of Electrical Departments of
NIAGARA
SYSTEM— Continued
Municipality. .
Population. . . .
Cayuga
705
Chatham
16,223
Chippawa
1,073
Clifford
454
Clinton
1,842
Earnings
Domestic service
Commercial light service. .
Commercial power service
Municipal power
Street lighting
Merchandise
Miscellaneous
Total earnings.
Expenses
Power purchased
Substation operation
Substation maintenance
Distribution system, operation and
maintenance
Line transformer maintenance
Meter maintenance
Consumers' premises expenses
Street lighting, operation and main-
tenance
Promotion of business
Billing and collecting
General office, salaries and expenses. .
Undistributed expenses
Truck operation and maintenance. . .
Interest
Sinking fund and principal payments
on debentures
Depreciation . .
Other reserves.
Total operating costs and fixed
charges
Net surplus
Net loss. . .
Number of Consumers
Domestic service
Commercial light service.
Power service
Total
3,271.60
2,867.78
1 ,404 . 86
1,431.00
12.92
79,868.02
67,913.97
46,853.22
4,799.33
19,009.95
329.77
1,133.54
* c
6,135.21
1,079.44
318.50
744.38
1,096.00
2,341.49
1,581.17
119.86
862.17
11,717.71
5,931.47
4,669.21
1,128.13
1,987.02
12.15
9.90
75.22
8,988.16
219,907.80
9,385.68
4,914.59
26,608.76
5,298.58
653 . 53
1.30
71.85
119,898.76
5,988.79
2,324.89
4,881.02
1,416.01
4,852.10
5,133.34
3,813.03
16,906.79
100.35
1,068.72
27.93
13.50
9.95
602 . 1 1
88.72
139.83
46.91
559.34
166.10
60.17
782.16
880.27
535.00
3,536.35
2,652.53
10,330.56
13,592.03
3,752.63
2,093.69
14,583.71
14,405.79
15,250.29
251.92
326.21
2.25
441.73
498 . 39
96.69
31.99
71.08
297.02
84.57
24.28
463 . 25
747.52
889.00
380.95
169.49
281.00
885 . 28
1,794.78
418.72
115.01
2,437.40
1,305.66
1,860.00
9,055.21
219,811.07
9,680.60
5,120.21
26,725.73
96.73
67.05
294 . 92
205.62
116.97
121
54
4
179
3,730
716
98
4,544
331
31
6
368
105
40
1
146
504
129
15
648
1934
HYDRO-ELECTRIC POWER COMMISSION
345
"B"— Continued
Hydro Municipalities for Year Ended December 31, 1933
Comber
P.V.
Cottam
P.V.
Courtright
348
Dashwood
P.V.
Delaware
P.V.
Dorchester
P.V.
Drayton
559
Dresden
1,488
$ c
2,354.18
2,292.75
3,049 S3
$ c
2,545.36
1,298.35
389.53
$ c.
1,604.43
941.55
98.47
792.82
774.00
$ c.
1,532.16
879.68
576.61
$ c.
1,331.90
601.43
$ c.
2,483.10
818.97
269.73
$ c.
3,093.75
1,887.84
1,017.47
$ c.
6,212.10
5,002.21
4,462.18
445 . 09
512.00
457.50
451.00
J264.00
590.00
750.00
1,758.36
150.42
76.09
84.24
31.18
112.02
158.18
118.77
230.00
200.62
8,284.85
4,774.98
4,242.45
3,551.47
2,355.51
4,280.57
6,979.06
18,230.98
6,315.79
2,582.55
3,137.10
2,543.64
1,439.07
3,257.94
5,684.26
12,059.91
99.98
113.58
98.55
9.30
. 15.54
135.93
27.10
24.94
79.35
67.51
202.16
1,761.19
20.35
60
8.11
123.57
68.88
106.33
57.75
30.23
25.72
28.88
110.98
237.30
262.24
237.23
37.98
"427'24
98.45
66.09
15.75
133.40
3.29
20.75
' 132'56
12.50
130.58
7.54
11.25
"252^33
28.09
616.53
558.01
76.85
119.65
472.48
434 . 00
397.23
355.91
338.00
248.36
593.46
215.00
128.10
111.56
204 . 00
115.83
144.91
145.00
134.24
148.31
335.00
403.00
287.98
516.00
70.88
691.43
841.00
225.00
8,068.58
4,428.69
4,447.50
3,311.50
2,050.80
4,225.54
7,484.80
17,261.67
216.27
346.29
205.05
239.97
304.71
55.03
505.74
969.31
98
49
3
105
28
1
58
23
2
66
27
1
48
18
124
26
1
147
58
4
372
122
10
150
134
83
94
66
151
209
504
346
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Detailed Operating Reports of Electrical Departments of
NIAGARA
SYSTEM— Continued
Municipality
Drumbo
P.V.
Dublin
P.V.
Dundas
5,138
Dunnville
3,615
Dutton
Population
761
Earnings
Domestic service
$ c.
2,130.97
1,039.19
753.76
$ c.
1,334.24
887.79
451.79
$ c.
20,753.93
10,660.40
16,577.44
594.35
5,388.00
$ c.
13,505.31
11,480.33
11,461.99
2,378.46
3,941.88
$ c.
3,545.07
2,534.26
3,552.14
Commercial light service
Commercial power service
Municipal power
Street lighting
522.50
750.00
999 37
Merchandise
Miscellaneous
77.89
286.71
222.89
270.99
Total earnings
4,524.31
3,423.82
54,260.83
42,990.86
10,901.83
Expenses
Power purchased
2,635.74
2,232.76
34,814.68
86.94
23,174.74
7,784.84
Substation operation
Substation maintenance
Distribution system, operation and
maintenance
208.09
60.93
5,250.20
37.12
828.99
1,718.56
20.93
137.69
362.81
Line transformer maintenance
183.13
Meter maintenance
107.72
116.98
Consumers' premises expenses
Street lighting, operation and main-
tenance
65.01
80.11
461.63
466.57
223.64
Promotion of business .
Billing and collecting
162.01
101.63
11.25
150.06
21.92
15.75
1,112.40
1,682.98
744.77
683.22
1,465.43
2,082.65
4,028.00
331.72
General office, salaries and expenses. .
Undistributed expenses
Truck operation and maintenance . . .
2,479.32
167.93
177.65
3,022.70
2,487.10
3,052.00
138.65
26.79
Interest
129.73
163.00
270.00
148.19
441.49
271.00
346.67
Sinking fund and principal payments
on debentures
340.60
Depreciation
548.00
Other reserves
Total operating costs and fixed
charges
3,854.18
3,422.21
53,279.01
36,905 . 19
10,403.83
Net surplus
670.13
1.61
981.82
6,085.67
498.00
Net loss .
Number of Consumers
Domestic service
82
25
1
40
22
3
1,219
193
40
766
199
34
204
Commercial light service
71
Power service
7
Total
108
65
1,452
999
282
1934
HYDRO-ELECTRIC POWER COMMISSION
347
"B"— Continued
Hydro Municipalities for Year Ended December 31, 1933
East
Windsor
14.333
East
York Twp.
Elmira
2,642
Elora
1,144
Embro
455
Erieau
264
Erie
Beach
23
Essex
1,888
$ c.
74,849.48
16,038.88
30,604 . 10
$ c.
175,276.26
23,952.07
22,408.69
5,117.31
19,637.45
$ c.
15,672.17
5,681.70
3,599.66
827.29
1,834.00
$ c.
7,125.01
3,524.48
2,907.45
$ c.
2,758.79
1,586.05
1,530.55
$ c.
3,652.19
1,058.34
879.43
$ c.
1,518.16
258.57
$ c.
7,502.00
4,666.24
4,383.42
1,669.44
8,419.92
1,674.00
96.94
397.09
672.00
360.00
3,134.99
142.38
442.39
61.67
502.16
129,912.38
246,534.16
28,057.21
15,724.97
6,609.06
5,949.96
1,776.73
21,858.25
73,289.08
158,535.98
20,696.12
10,335.79
4,285.42
3,747.85
877.83
11,571.99
6,497.35
317.06
7,781.53
2,102.43
3,006.62
1,147.19
2,074.15
1,768.00
2,432.24
17.56
68.16
79.77
23.14
4.68
106.41
55.35
89.42
175.27
232.7a
49.42
2,799.55
2,459.49
124.63
11.34
64.66
2,718.77
105.99
148.71
204.55
54.82
282.06
2,480.64
10,294.90
4,553.33
3,029.19
3,062.93
10,636.12
9,862.66
3,817.34
3,770.91
15,151.56
14,214.38
12,772.00
221.63
635.45
716.84
412.43
158.85
1,457.16
1,573.21
1,978.00
691.55
454.05
364.32
105.04
237.19
732.10
1,070.00
343.12
141.51
17.59
319.65
118.19
61.32
160.38
8.16
7.50
778.48
1,927.41
159.90
213.97
3,581.12
6.708.47
7,767.00
228.61
434.85
477.00
313.92
324.96
325.00
161.51
127.23
76.00
1,071.96
476.71
1,638.00
129,558.88
245,094.50
29,626.68
16,656.71
6,240.24
5,516.89
1,605.22
18,467.34
353.50
1,439.66
368.82
433.07
171.51
3,390.91
1,569.47
931.74
2,971
266
33
8,744
367
35
505
115
22
307
73
2
99
45
1
138
12
2
63
3
413
112
17
3,270
9,146
642
382
145
152
66
542
348
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Detailed Operating Reports of Electrical Departments of
NIAGARA
SYSTEM— Continued
Municipality
Population . .
Etobicoke
Twp.
Exeter
1,622
Fergus
2,559
Fonthill
862
Forest
1,465
Earnings
Domestic service
Commercial light service. .
Commercial power service.
Municipal power
Street lighting
Merchandise
Miscellaneous
93,889.08
16,220.69
11,212.72
4,478.63
13,415.13
* c.
11,406.32
4,896.67
4,064.90
542.21
1,998.94
15,720.00
6,278.16
7,615.45
799.21
2,915.04
102.64
4,877.99
974.73
238.17
358.68
1,065.00
394.27
570.76
8.59
* c.
10,865.60
5,208.04
4,209.01
1,062.18
2,321.00
49.28
652.87
Total earnings.
139,610.52
23,479.80
33,430.50
7,523.16
24,367.98
and
Expenses
Power purchased
Substation operation
Substation maintenance
Distribution system, operation
maintenance
Line transformer maintenance
Meter maintenance
Consumers' premises expenses
Street lighting, operation and main-
tenance
Promotion of business
Billing and collecting
General office, salaries and expenses. .
Undistributed expenses
Truck operation and maintenance. . .
Interest
Sinking fund and principal payments
on debentures
86,749.14
15.467.63
23,979.90
3,816.05
14,351.36
8,161.68
679.56
1,199.31
566.83
34.20
326.61
Depreciation . .
Other reserves.
1,515.61
1,045.34
4,436.42
2,655.76
2,535.06
1,645.09
11,330.30
11,534.81
10,411.00
264.73
77.96
423.42
2,174.67
109.12
101.52
458.58
960.47
1,334.00
1,216.19
72.50
396.64
12.00
290.68
570.53
703.43
102.81
42.35
30
367.88
630.82
768.22
207.43
281.63
1,135.77
2,836.71
1,510.00
486.84
1,019.53
1,020.98
472.00
497.48
2,214.48
196.97
284.37
645 . 65
1,056.82
1,389.00
Total operating costs and fixed
charges
143,899.08
22,299.74
33,338.49
7,428.58
21,810.25
Net surplus.
Net loss. . .
180.06
92.01
94.58
2,557.73
4,288.56
Number of Consumers
Domestic service
Commercial light service
Power service
Total
3,114
212
22
3,348
452
121
9
582
618
116
13
747
194
33
5
232
458
139
24
621
934
HYDRO-ELECTRIC POWER COMMISSION
349
"B"— Continued
Hydro Municipalities for Year Ended December 31, 1933
Gait
14,036
George-
town
2,187
Glencoe
800
Goderich
4,366
Granton
P.V.
Guelph
20,754
Hagers-
ville
1,370
Hamilton
154,701
$ c.
103,490.42
41,981.08
72,488.00
4,441.00
$ c.
14,067.98
6,022.90
22,190.68
506.49
2,125.83
$ c.
5,470.81
3,152.02
1,541.71
1,432.99
1,934.00
$ c.
29,614.29
13,509.59
10,640.48
3,429.33
3,791.50
$ c.
1,692.71
1,028.21
830 . 74
$ c.
103,446.51
49,053.55
95,347.14
11,864.16
18,499.79
755.77
1,488.05
$ c.
4,816.57
4,468.97
11,477.85
$ c.
896,836.05
346,737.41
1,453,362.29
54,487.69
21,384.00
370.00
1,732.00
39.69
859.54
123,449.34
3,295.62
737.63
41.24
187.81
175.66
22,459.92
247,080.12
45,651.51
13,572.77
61,173.00
4,097.32
280,454.97
23,394.62
2,897,332.70
157,535.71
4,287.58
35,878.07
9,215.72
41,623.21
1,750.09
3,110.71
210,624.16
3,044.97
19,561.72
2,048,010.95
61,889.21
75.93
8,450.50
2,914.71
67.52
1,053.03
37.09
344.98
582.40
2,215.79
171.64
543.81
121.42
9,751.83
705.37
2,821.57
210.69
6,996.40
219.75
6,000.48
8,653.05
4,432.87
1,323.37
2,774.40
5,656.52
12,845.00
2,655.22
83.11
183.71
36,860.80
9,473.80
2,876.05
17,589.68
14,698.25
3,153.09
4,358.94
274.80
222.10
623.28
18.52
128.14
13,053.04
17,737.88
3,798.16
3,797.30
4,270.43
733.80
1,638.32
782.25
168.01
543.13
691.85
765.41
1,982.00
532.69
333.84
46.49
126.17
539.24
981.45
906.00
1,826.10
2,134.74
218.67
203.68
2,714.49
2,231.60
5,189.00
159.75
85.85
15.98
540.44
660.12
146.71
544.40
177.04
373.76
1,068.00
50,189.04
42,784.91
43,371.88
16,351.29
18,563.27
22,878.00
3,000.00
143.70
119.18
221.00
250,855.06
292,021.39
127,175.00
248,661.78
44,158.94
13,486.10
61,446.10
3,996.11
276,060.43
26,122.37
3,034,161.39
1,492.57
86.67
101.21
4,394.54
1,581.66
273.10
2,727.75
136,828.69
3,584
484
118
668
132
27
218
80
6
1,155
237
20
80
33
2
5,008
760
130
316
107
17
36,990
5,068
1,265
4,186
827
304
1,412
115
5,898
400
43,323
350
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Detailed Operating Reports of Electrical Departments of
NIAGARA
SYSTEM— Continued
Municipality
Harriston
1,293
Harrow
926
Hensall
719
Hespeler
2,784
Highgate
338
Population
Earnings
$ c.
7,829.33
4,842.28
5,091.22
477.06
1,467.00
$ c.
7,875.06
3,499.99
3,558.36
1,249.44
$ c.
4,180.44
1,800.34
2,518.55
37.56
996.00
$ c.
18,265.53
4,916.32
35,121.46
1,103.95
2,965.00
$ c.
1,783.58
976 17
Commercial light service
Commercial power service
1,081.68
39 01
Street light
568.00
Merchandise
Miscellaneous
50.19
244.24
496.57
170.08
Total earnings
19,706.89
16,233.04
9,777.13
62,868.83
4,618.52
Expenses
Power purchased
13,089.24
12,347.82
6,992.59
49,949.40
310.84
11.00
2,384.26
42.72
169.36
2,972.71
Substation maintenance
Distribution system, operation and
maintenance
1,182.25
150.05
16.94
125.71
332.27
37.77
Line transformer maintenance
Meter maintenance
145.25
9 40
Consumers' premises expenses
Street lighting, operation and main-
tenance
Promotion of business
267.68
273.32
53.88
632.60
437.12
28.25
114.10
602.72
97.52
Billing and collecting
825.74
118.11
93.03
165.77
577.59
721.66
953.00
348.50
415.07
29.35
661.59
1,257.96
482.34
289.16
2,000.75
2,735.69
2,492.00
348.63
General office, salaries and expenses. .
Undistributed expenses
Truck operation and maintenance . . .
Interest
Sinking fund and principal payments
on debentures
Depreciation
133.12
15.75
526.23
519.93
682 00
438.95
423.48
625.00
177.84
165.85
333.00
Other reserves
Total operating costs and fixed
charges
18,139.32
15,793.85
9,719.31
63,389.79
4,291.59
Net surplus
Net loss
1,567.57
439.19
57.82
326.93
520.96
Number of Consumers
Domestic service
Commercial light service
Power service
338
105
12
246
77
4
180
52
14
700
108
28
96
37
6
Total
455
327
246
836
139
1934
HYDRO-ELECTRIC POWER COMMISSION
351
"B"— Continued
Hydro Municipalities for Year Ended December 31, 1933
H umber-
stone
2,265
Ingersoll
5,296
Jarvis
504
Kingsville
2,286
Kitchener
31,443
Lambeth
P.V.
La Salle
600
Leaming-
ton
5,025
$ c.
8,447.65
2,998.76
3,912.05
$ c.
31,581.32
14,380.17
23,673.54
2,039.45
4,851.48
10.98
542.47
$ c.
2,396.78
1,868.82
4,220.35
' 840'00
$ c.
14,073.03
6,544.89
3,366.09
1,207.24
3,220.00
$ c.
193,447.44
98,357.80
197,453.09
20,660.15
32,415.74
$ c.
3,387.28
1,511.67
576.57
459.00
$ c.
6,313.91
1,666.45
2,254.05
$ c.
25,306.03
13,751.06
10,924.25
5,324.06
1,367.00
577.50
5,456.34
464 . 80
97.18
1,124.79
864.43
56.28
143.22
875.61
17,190.26
77,079.41
9,423.13
29,536.04
543,198.65
5,990.80
10,955.13
61,637.35
9,429.08
60,705.42
717.50
6,751.50
16,082.70
403,835.00
8,771.81
797.95
14,680.84
161.81
4,404.47
1,378.55
6,701.85
663.38
13,044.80
13,430.50
5,575.44
3,851.29
11,657.75
24,044.92
28,993.00
2,564.88
4,033.14
6,926.92
37,851.83
814.30
2.40
2,674.64
562.49
148.22
189.53
510.23
58.10
1,386.15
4,635.02
442.72
411.07
3,387.13
1,677.35
3,335.00
171.40
" 20 '. 50
1,008.75
99.92
249.01
51.32
3.82
127.38
426.32
2,637.19
47.21
26.80
603 . 14
62.43
122.38
45.10
658.69
47.50
90.00
939.31
505.95
36.73
23.72
1,335.45
1,032.46
380.50
191.77
1,758.32
675.37
1,883.00
"217.33
15.00
155.74
136.24
326.00
571.10
503.40
74.52
321.89
722.91
633.57
795.00
2,306.04
2,965.10
719 13
839.28
113.43
500.34
1,230.95
1,200.00
1,040.00
391.07
487.57
386.00
2,105.11
2,079.75
3,218.00
14,818.62
80,840.57
8,819.54
25,355.94
544,558.24
5,113.47
11,065.63
56,034.58
2,371.64
603.59
4,180.10
877.33
5,602.77
3,761.16
1,359.59
110 50
500
64
7
1,265
234
44
120
36
4
706
174
14
7,117
956
239
109
28
2
198
21
5
1,324
255
26
571
1,543
160
894
8,312
139
224
1,605
352
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Detailed Operating Reports of Electrical Departments of
NIAGARA
SYSTEM— Continued
Municipality
Population
Listowel
2,665
London
73,173
London
Twp.
Long
Branch
3,541
Lucan
590
Earnings
Domestic service
$ c.
17,760.49
7,947.24
11,468.64
1,504.67
3,839.10
$ c.
492,592.98
188,474.27
316,997.15
49,029.36
54,028.74
2,894.60
31,413.71
$ c.
10,610.79
2,446.39
1,537.05
$ c.
23,463.32
5,270.04
779.45
994.12
3,413.27
$ c.
4,777 67
Commercial light service
Commercial power service
Municipal power
Street lighting
Merchandise
1,617.17
370.86
832.50
992.70
Miscellaneous
642.62
413.43
108.00
316 54
Total earnings
43,162.76
1,135,430.81
15,840.16
34 ; 028.20
8,074.94
Expenses
Power purchased
Substation operation
Substation maintenance
31,664.62
59.72
762,305.39
16,101.15
11,647.78
19,767.37
3,134.48
13,465.77
4,466.07
10,172.51
5,969.48
26,778.58
33,679.83
10,257.36
6,431.59
48,462.11
63,052.93
91,824.95
12,166.28
11,062.35
20,475.98
4,911.08
Distribution system, operation and
maintenance
Line transformer maintenance
2,560.37
244.27
556.56
287.19
3,418.08
56.99
229.85
609.43
Meter maintenance
246.96
Consumers' premises expenses
Street lighting, operation and main-
tenance
405.96
11.54
812.58
617.08
321.31
173.88
549.34
1,722.10
2,525.00
161.49
7.11
600.28
665 . 10
22.38
536.33
11.25
2,093.32
1,934.47
869.09
130.15
Promotion of business
Billing and collecting
504.63
General office, salaries and expenses. .
Undistributed expenses
Truck operation and maintenance. . .
Interest
Sinking fund and principal payments
on debentures
400.37
40.76
672.27
965.35
690.00
1,988.88
1,899.79
2,166.00
229.14
258.75
Depreciation
625.00
Other reserves
Total operating costs and fixed
fixed charges
42,224.33
1,139,683.63
15,380.48
35,680.03
7,709.31
Net surplus
938.43
459.68
365.63
Net loss
4,252.82
1,651.83
Number of Consumers
Domestic service
726
152
21
16,367
2,839
486
330
19
5
899
68
3
174
Commercial light service
Power service
44
7
Total
899
19,692
354
970
225
1934
HYDRO-ELECTRIC POWER COMMISSION
353
"B"— Continued
Hydro Municipalities for Year Ended December 31, 1933
Lynden
P.V.
Markham
1,073
Merlin
P.V.
Merritton
2,544
Milton
1,828
Milverton
1,004
Mimico
6,454
Mitchell
1,571
$ c.
2,151.80
713.59
749.82
$ c.
6,880.40
2,614.73
2,772.35
490 . 25
1,356.00
$ c.
2,261.27
1,704.94
1,470.08
$ c.
11,558.62
2,241.79
59,639.69
$ c.
11,622.25
5,463.21
11,308.00
$ c.
5,672.73
2,775.02
3,544.03
549.60
999.00
$ c.
54,604.89
9,519.99
3,477.41
7,700.76
8,021.89
$ c.
10,478.52
4,196.91
4,080.52
830 22
431.80
688.00
3,352.00
2,019.50
2,088.00
927.11
7.53
160.67
326.39
267.85
1,740.01
87.10
121.05
190.59
4,054.54
14,274.40
6,450.68
77,059.95
32,152.97
13,627.48
83,445.99
22,791.87
3,247.16
9,272.27
3,979.24
64,931.76
20,567.45
244.13
10,295.00
53,807.49
14,560.37
102 77
64.20
947.59
89.98
3,073.20
1,660.68
329.65
7,089.10
71.31
950.83
13.00
1,166.74
670.34
11.59
74.49
390.07
346.18
187.22
3.57
85.37
220 80
2.59
194.47
43.17
57.50
864.00
218.87
166.00
935.85
2,107.06
200.38
355.63
1,532.64
2,218.30
408.91
160.49
298.80
301.84
15.00
"505.95
671.76
355.00
1,029.67
1,845.88
193.05
339.22
1,194.75
1,503.67
1,996.00
537.65
313.93
191.66
172 .72
677.11
676.00
675.00
1,637.61
2,155.82
313.27
626.50
5,000.91
5,353.04
5,235.00
1,040.94
1,463.54
661 46
60.61
20.00
778.52
169.85
92.36
371.51
779.00
118 90
155.08
154.20
2.25
266.00
2,899.00
4,182.50
12,608.16
6,349.56
77,361.27
30,553.17
14,144.88
83,420.62
22,149.28
1,666.24
101.12
1,599.80
25.37
642 59
127.96
301.32
517.40
81
21
1
272
66
11
104
45
2
700
60
11
456
104
21
223
71
7
1,760
138
15
429
99
24
103
349
151
771
581
301
1,913
552
354
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Detailed Operating Reports of Electrical Departments of
NIAGARA
SYSTEM— Continued
Municipality
Population. .
Moore-
field
P.V.
Mount
Brydges
P.V.
Newbury
267
New
Hamburg
1,426
New
Toronto
7,280
Earnings
Domestic service
Commercial light service. .
Commercial power service.
Municipal power
Street lighting
Merchandise
Miscellaneous
1,068.82
647.64
1,161.94
2.832.07
915.76
917.24
1,266.73
957.67
760.22
10,770.96
4,255.63
4,594.44
375.00
54.73
500.00
211.45
720.00
24.86
2,258.75
229.14
173.23
32,307.33
12,113.15
95,773.91
10,926.65
8,913.96
Total earnings
3,308.13
5,376.52
3,729.48
22,282.15
160,035.00
and
Expenses
Power purchased
Substation operation
Substation maintenance
Distribution system, operation
maintenance
Line transformer maintenance
Meter maintenance
Consumers' premises expenses
Street lighting, operation and main-
tenance
Promotion of business
Billing and collecting
General office, salaries and expenses. .
Undistributed expenses
Truck operation and maintenance . . .
Interest
Sinking fund and principal payments
on debentures
2,699.72
3,548.38
2,254.82
15,516.92
369.04
135,895.07
21.60
176.30
55 '93
98.95
319.24
497.92
25.31
43.75
48.70
118.82
173.57
106.30
21.73
124.83
15.75
Depreciation . .
Other reserves
94.38
290.65
185.00
137.64
152.72
290.00
295.96
500.00
287.00
353.29
29.09
562.06
839.54
116.20
232.15
385.97
792.52
1,300.00
4,627.57
337.04
636.05
247.38
1,777.42
2,703.22
4,806.67
1,468.24
1,157.29
827.68
304.25
5,205.00
Total operating costs and fixed
charges
3,435.48
4,706.32
3,626.01
21,313.94
159,992.88
Net surplus
Net loss . . .
670.20
103.47
968.21
42.12
127.35
Number of Consumers
Domestic service
Commercial light service.
Power service. „
Total.
136
36
3
175
343
93
14
450
1,434
151
34
1,619
1934
HYDRO-ELECTRIC POWER COMMISSION
355
"B"— Continued
Hydro Municipalities for Year Ended December 31, 1933
Niagara
Falls
18,507
Niagara-on-
the-Lake
1,672
North York
Twp.
Norwich
1,126
Oil
Springs
433
Otterville
P.V.
Palmerston
1,617
Paris
4,330
$ c.
138,423.29
55,590.67
49,627.60
15,238.33
28,392.66
$ c.
14,217.28
3,410.85
852.84
1,621.21
2,833.31
277.05
322.31
$ c.
94,813.34
15,325.38
27,640.58
3,927.85
3,675.61
$ C
8,128.33
3,068.33
1,595.16
634.90
2,120.00
94.35
192.95
$ c.
1,636.56
1,168.42
7,848.65
$ c.
2,115.40
1,656.94
160 65
108.10
780.51
$ c.
10,859.15
4,888.74
4,666.92
1,900.85
1,738.98
$ c.
22,861.22
8,245.31
12,373.70
1,225 00
750.00
5,838.90
59.69
480.97
222.67
124.91
6.32
1,798.24
287,332.24
23,534.85
145,863.73
15,834.02
11,626.30
4,946.51
24,060.96
52,342.37
181,553.04
10,386.43
13,429.40
81,895.54
11,067.84
7,107.19
3,596.84
17,853.90
33,767.22
170.46
8,858.38
168.28
2,362.97
10,471.07
369.63
1,363.61
1,467.21
535.44
43.30
16.04
74.92
649.80
29.15
189.60
4,756.19
114.61
5,442.10
69.68
59.66
25.67
422.15
96.36
3,355.89
485.67
674.97
263.59
39.47
70.56
355.74
660.87
7,215.69
4,434.66
3,648.88
2,610.56
3,298.98
20,862.62
15,944.89
11,206.00
412.61
309.13
178.85
176.20
332.92
565.34
822.00
373.63
349.42
82.73
252.77
75.94
19.50
656.76
764.26
99.37
115.45
366.42
863.87
1,213.00
1,245.42
8,844.93
4,940.08
1,950.20
1,249.33
303.78
3,348.62
331.58
1,220.07
949 . 10
1,519.00
352.11
20,800.73
24,472.06
23,016.00
364.39
1,128.19
691.00
73.13
329.40
410 00
564.23
696.52
4,915.00
186.89
302,402.23
22,317.67
156,781.41
15,655.35
10,697.13
4,962.40
23,157.32
49,501.14
1,217.18
178.67
929.17
903.64
2,841.23
15,069.99
10,917.68
15.89
4,329
669
87
464
82
10
2,802
233
36
359
77
7
75
30
31
102
43
4
389
90
11
1,060
180
27
5,085
556
3,071
443
136
149
490
1,267
356
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Detailed Operating Reports of Electrical Departments of
NIAGARA
SYSTEM— Continued
Municipality
Parkhill
998
Petrolia
2,569
Plattsville
P.V.
Point
Edward
1,211
Port
Population
Colborne
6,006
Earnings
Domestic service
$ c.
4,742.41
3,052.58
287.57
538.80
1,437.00
$ c.
11,576.04
6,517.41
21,684.65
$ c.
2,610.72
1,055.17
532.83
$ c.
5,693.23
2,009.55
17,972.48
$ c.
27,055.82
11,314.48
6,914.32
6,419.45
7,825.80
Commercial light service
Commercial, power service
Municipal power
Street lighting
2,652.00
238.00
474.65
442.00
1,553.66
Merchandise
Aliscellaneous
11.25
13.18
625.73
Total earnings
10,069.61
43,142.75
4,653.90
27,854.65
59,529.87
Expenses
Power purchased
Substation operation
7,747.92
27,646.63
3,065.25
22,880.12
35,390.98
Substation maintenance
Distribution system, operation and
261.19
2,497.23
667.76
298.02
62.40
397.55
15.15
164.10
1 838 03
Line transformer maintenance
337 74
Meter maintenance
170.70
898 . 09
Consumers' premises expenses
81.56
Street lighting, operation and main-
222.30
371.74
225.64
1,934.93
Promotion of business
726.10
Billing and collecting
General office, salaries and expenses. .
Undistributed expenses
Truck operation and maintenance. . .
251.15
108.20
24.74
457.21
2,032.92
246.29
201.03
1,479.45
2,236.50
2,807.00
400.00
166.85
7.86
15.75
"l, 848. 80
80.51
1,614.19
3,357.49
287.30
1,071.08
418.56
982.52
691.00
151.00
189.67
254.00
536.43
945 . 69
1,045.00
4,328.06
Sinking fund and principal payments
6,754.90
Depreciation
4,242.00
Other reserves
Total operating costs and fixed
charges
10,878.28
41,341.78
3,912.78
28,138.99
62,862.45
Net surplus
1,800.97
741.12
Net loss
808.67
284.34
3,332.58
Number of Consumers
Domestic service
238
79
4
667
167
55
91
26
1
300
44
9
1,249
Commercial light service
224
25
Total
321
889
118
353
1,498
1934
HYDRO-ELECTRIC POWER COMMISSION
357
"B"— Continued
Hydro Municipalities for Year Ended December 31, 1933
Port
Credit
1,650
Port
Dalhousie
1,331
Port
Dover
1,680
Port
Rowan
674
Port
Stanley
723
Preston
6,138
Princeton
P.V.
Queenston
P.V.
$ c.
13,127.25
4,609.43
892.93
1,311 .91
$ c.
13,147.96
2,736.23
5,038.13
$ c.
8,036.80
4,405.46
4,976.57
$ c.
3,479.35
1,657.90
90.49
$ c.
12,781.37
3,704.61
3,470.65
727.80
2,003.16
$ c.
40,489.55
15,920.17
32,698.58
954.78
4,986.96
$ c.
2,143.41
697.24
3,075.76
$ c.
2,539.83
818.72
187.73
2,710.00
1,630.00
2,964.17
1,242.00
481.00
456.10
39.50
143.34
307.70
965.27
15.83
32.00
22,691.02
22,695.66
20,383.00
6,469.74
22,995.29
96,015.31
6,413.24
4,034.38
18,405.63
15,064.63
11,301.52
3,799.50
13,687.99
65,046.64
4,301.33
22.96
2,559.87
438.79
1,256.03
98.73
884.59
52.16
1,693.98
1,499.78
815.07
650.66
2,831.28
5,185.56
8,095.00
100.00
5,082.38
2,318.16
837.14
39.24
1,652.03
439.26
936.71
56.86
151.60
246.25
2,080.79
2.60
133.50
60.82
199.22
52.35
55.78
21.95
326.73
261.00
346.75
48.61
173.62
75.58
67.54
1,192.01
411.33
53.19
657.00
786.86
70.44
336.80
663.30
1,277.85
947.00
454 . 66
292.58
30.98
204.00
188.66
23.41
617.47
598.46
115.19
205.65
411.44
821.38
1,231.00
160.75
34.75
22.50
"324.05
416.49
535.09
1,466.00
800 . 23
2,094.47
1,260.00
1,009.32
400.17
338.00
104.06
128.58
244.00
346.57
465.37
318.00
23,757.15
22,156.17
17,726.36
6,313.70
20,079.09
95,532.43
5,913.42
4,038.91
539.49
2,656.64
156.04
2,916.20
482.88
499 . 82
1,066.13
4.53
400
72
6
587
55
10
476
122
12
101
30
1
596
97
10
1,552
237
57
77
20
3
68
11
1
478
652
610
132
703
1,846
100
80
338
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Detailed Operating Reports of Electrical Departments of
NIAGARA
SYSTEM— Continued
Municipality
Richmond
Hill
1,270
Ridgetown
1,942
Riverside
5,125
Rockwood
P.V.
Rodney
757
Population
Earnings
Domestic service
$ c.
7,421.53
3,736.73
2,507.11
472.46
1,389.00
52.93
1 16 . 28
$ c.
9,111.63
4,836.72
3,477.74
827.82
3,115.00
141.12
637.53
$ c.
38,813.62
4,275.26
7,569.56
2,087.37
2,919.72
$ c.
2,976.57
948.07
257.99
$ c.
3,349.64
Commercial light service
Commercial power service
2,393.00
2,172.43
Municipal power
Street lighting
765.00
1,032.02
Merchandise
Miscellaneous
255.37
53.83
150.00
Total earnings
15,696.04
22,147.56
55,920.90
5,001.46
9,097 09
Expenses
Power purchased
9,004.24
16,469.32
38,002.59
3,814.30
6,127.85
Substation operation
Substation maintenance
Distribution system, operation and
maintenance
1,258.92
1,108.70
246 . 14
522.16
62.09
459.66
859.37
89.42
1,012.70
943.00
835.60
865.47
3,635 . 25
1,783.18
1,133.43
943 . 13
3,491.29
3,761.13
3,871.00
145.33
404.14
Line transformer maintenance
Meter maintenance
45.78
148.72
Consumers' premises expenses
Street lighting, operation and main-
tenance
229.97
64.50
184.30
Promotion of business . .
Billing and collecting
1,024.60
940.62
74.10
167.18
415.26
357.66
1,300.00
347.50
General office, salaries and expenses. .
Undistributed expenses
600.21
444 . 78
22.92
245.57
29.51
Truck operation and maintenance. . .
Interest
257.60
677.16
533.00
121.22
79.39
427.00
314.96
Sinking fund and principal payments
on debentures
276.37
Depreciation
425.00
Other reserves
Total operating costs and fixed
charges
12,561.10
23,147.49
61,226.56
5,165.22
8,503.92
Net surplus . .
3,134.94
593.17
Net loss
999.93
5,305.66
163.76
Number of Consumers
Domestic service
321
60
17
557
144
24
1,081
47
8
145
34
2
202
Commercial light service. '.
73
Power service
7
Total
398
725
1 136
181
282
1934
HYDRO-ELECTRIC POWER COMMISSION
359
"B"— Continued
Hydro Municipalities for Year Ended December 31, 1933
St. Catharines
26,192
St. Clair
Beach
St. George
P.V.
St. Jacobs
P.V.
St. Marys
4,016
St. Thomas
16,275
Sandwich
11,017
$ c.
144,062.04
47,684.43
86,508.23
$ c
2,297.25
1,133.89
374.68
$ c
2,876.52
1,026.14
2,168.29
$ c.
3,829.52
1,134.57
1,030.20
$ c
28,360.01
9,291.65
14,183.81
2,674.49
4,096.75
189.10
187.53
$ c
107,077.52
46,670. W
42,915.85
5,617.68
14,604.46
$ c.
88,361.44
16,649 87
12,067.13
20,524.24
370.50
460.00
9,874.46
140.31
4,262.84
110.99
160.58
2,789.64
562.62
303,041.78
3,805.86
6,552.44
6,614.87
58,983.34
219,675.44
127,655.83
190,682.11
4,174.09
2,786.45
5,749.34
5,359.74
46,680.61
1,150.76
95.82
2,551.90
424.48
745.87
34.35
1,315.80
158,232.48
6,982.45
1,549.23
9,668.72
889 . 16
2,137.46
1,799.33
3,004.44
52.74
4.783.04
11,000.52
4,119.52
1,419.87
1,475.83
4,839.07
12,610.00
91,437.13
24.40
12,430.10
1,228.63
136.34
22.93
55.97
27.55
57.13
53.48
1,639.56
416.55
5,555.09
231.73
1,815.72
2,266.58
318.21
3,251.98
68.15
31.65
3.00
1,752.01
38.00
29.57
185.75
31.59
97.92
63.28
261.71
333.73
317.00
9,760.82
545.96
51.51
24.20
1,283.72
1,208.30
622.91
514.84
2,322.37
2,163.58
4,388.00
90.15
5,511.82
10,761.91
4,436.52
430.40
5,865.36
1,270.33
2,101.48
1,098.92
11,977.28
12,950.11
16,868.00
196.81
216.02
300.00
117.90
384.19
349.00
6,210.56
6,450.31
5,735.00
288,482.70
4,349.79
7,440.85
6,729.36
65,593.46
224,563.86
129,545 88
14,559.08
543.93
888.41
114.49
6,610.12
4,888.42
1,890.05
6,361
710
152
38
8
2
132
36
3
109
28
6
1,034
195
37
3,999
635
80
2,392
210
29
7,223
48
171
143
1,266
4,714
2,631
360
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Detailed Operating Reports of Electrical Departments of
NIAGARA
SYSTEM— Continued
Sarnia
17,801
Scarboro'
Twp.
Seaforth
1,692
Simcoe
5,397
Springfield
379
Population
Earnings
Domestic service
$ c.
104.443.09
45,760.80
167,781.48
$ c.
88,543.29
17,694.05
9,958.30
11,227.44
14,911.65
$ c.
10,808.12
5,076.86
4,162.74
656.01
1,788.00
398.56
608.31
$ c.
20,283.75
24,148.61
23,340.23
2,388.41
4,527.48
$ c.
1,656.59
707 14
Commercial light service
1,060.65
Municipal power
Street lighting
18,456.98
550 00
Merchandise
Miscellaneous
4,016.71
436.55
717 58
251 83
Total earnings
340,459.06
142,771.28
23,498.60
75,406.06
4,226.21
Expenses
237,328.45
8,228.99
354.75
6,876.14
769.34
3,333.21
82,430.26
16,215.02
44,150.24
467 . 24
3,662.78
Substation maintenance
123.27
5,822.56
1,093.99
1,106.31
296.62
1,723.58
7.95
1,578.14
" 126.77
Distribution system, operation and
maintenance
3,740.82
89.99
1,422.07
135.94
853.99
71.64
1,523.73
2,185.73
649 . 24
587.52
2,711.63
2,948.96
3,360.00
10.48
Line transformer maintenance
Meter maintenance
100.40
Consumers' premises expenses
Street lighting, operation and main-
tenance
6,041.61
1,842.59
6,689.54
10,747.76
5,858.44
2,816.90
8,864.06
20,422.66
17,715.00
330.00
67.08
Promotion of business
Billing and collecting
5,586.84
6,335.47
2,811.20
1,841.98
11,728.27
13,386.95
10,650.00
130.00
830.36
369.55
108.89
192.35
1,251.60
445 . 75
1,752.00
300.19
General office, salaries and expenses. .
Undistributed expenses
71.37
21.25
Truck operation and maintenance. . .
Interest
211.16
Sinking fund and principal payments
on debentures . .
168.66
Depreciation . .
337.00
Other reserves
Total operating costs and fixed
charges
337,889.44
145,067.30
23,208.38
64,898.74
4,950.37
Net surplus
2,569.62
290.22
10,507.32
Net loss
2,296.02
724.16
Number of Consumers
Domestic service
4,546
610
85
4,404
361
30
391
105
15
1,144
306
38
98
Commercial light service
30
Power service
3
Total
5,241
4,795
511
1,488
131
1934
HYDRO-ELECTRIC POWER COMMISSION
36
"B"— Continued
Hydro Municipalities for Year Ended December 31, 1933
Stamford
Twp.
Stouffville
1,105
Stratford
18,869
Strathroy
2,879
Sutton
809
Tavistock
1,042
Tecum seh
2,546
Thames-
ford
P.V.
$ c.
51,719.41
6,593.80
3,852.98
1,826.90
$ c.
7,124.57
2,739.57
839.91
$ c.
146,586.63
51,772.30
51,420.95
12,209.44
16,539.00
$ c.
20,207.78
9,754.05
9,319.2(9
1,501.00
4,075.71
$ c.
7,578.25
2,981.82
1,073.01
$ c.
6,906.75
2,051.73
8,476.95
460.57
1,212.00
$ c.
14,603.68
3,171.42
1,322.34
$ c.
2,428.13
1,310.32
2,979.91
7,914.64
1,764.00
1,861.00
960.00
517.00
324.25
6,495.66
1,015.18
152.28
250.99
344.88
71,907.73
12,792.30
285,023.98
45,873.01
13,646.36
19,358.99
20,057.44
7,580.24
36,822.04
503.82
8,131.48
200,007.95
4,994.95
870.56
6,116.52
553.36
1,488.50
323.25
3,232.58
616.95
6,056.05
4,372.10
6,797.02
1,015.36
21,775.00
9,239.60
19,951.00
1,208.87
28,976.73
221.40
261.99
1,578.12
340.87
518.94
8,932.52
16,964.12
10,658.85
6,245.97
5,422.41
139.06
625.49
333.52
463.47
523.42
39.68
373.40
297.99
191.10
421.48
1,684.40
408.03
450.04
409.85
1,406.54
1,317.64
1,457.00
218.43
9.16
1,236.37
23.73
157.71
1,630.12
712.43
133.60
692.34
261.97
797.48
1,740.35
391.30
298.53
1,884.42
1,633.32
3,140.00
129.75
46.98
49.85
3,066.06
502.97
65.17
47.61
622.54
167.40
55.95
173.97
3,684.60
1,368.67
408.53
89.88
19 50
1,870.51
9,504.11
10,555.98
5,783.00
447.76
1,512.84
505.00
972.93
1,346.60
830.00
201.03
197.13
777.00
95.49
206.55
427.00
82,299.18
11,764.70
288,619.62
42,737.76
13,161.07
19,519.35
19,639.42
7,693.51
1,027.60
3,135.25
485 . 29
418.02
10,391.45
3,595.64
160.36
113.27
1,645
111
13
336
80
5
4,293
614
132
802
173
25
382
84
5
261
68
6
506
47
3
121
39
7
1,769
421
5,039
1,000
471
335
556
167
362
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Detailed Operating Reports of Electrical Departments of
NIAGARA
SYSTEM— Continued
Municipality
Thames-
ville
754
Thedford
577
Thorndale
P.V.
Thorold
5,068
Tilbury
1,996
Population
Earnings
Domestic service
$ c.
4,003.41
2,756.04
2,111.24
249.46
1,191.00
$ c.
3,152.75
1,796.45
1,599.64
$ c.
1,432.95
920.15
254.32
$ c.
18,732.14
6,486.84
26,575.95
2,901.88
3,551.00
$ c.
6,539.15
6,999.33
6,888.96
229.50
Commercial light service
Commercial power service
Municipal power
Street lighting
1,035.00
384.00
1,580.22
Merchandise
Miscellaneous
337.31
50.90
2.62
388.87
574.88
Total earnings
10,648.46
7,634.74
2,994.04
58,636.68
22,812.04
Expenses
Power purchased
6,500.46
4,712 96
2,711.26
45,747.53
2,015.75
14,547.09
Substation maintenance
Distribution system, operation and
maintenance
504.14
108.30
30.44
2,969.32
1,347.33
38.92
Line transformer maintenance
Meter maintenance .
157.43
42.49
276.45
174 66
Consumers' premises expenses
Street lighting, operation and main-
tenance
235.47
67.10
47.00
575.43
273.37
Promotion of business
Billing and collecting. .
206.63
318.53
38.50
207 . 86
81.85
20.43
55.34
5.10
17.75
1,169.17
878.65
373.93
372.70
644.29
General office, salaries and expenses . .
Undistributed expenses
529.70
196.13
Truck operation and maintenance . . .
Interest
280.22
560.42
735.00
633.83
851.48
380.00
75.56
87.07
230.00
437.94
Sinking fund and principal payments
on debentures
637.27
Depreciation
2,660.00
1,121.00
Other reserves
Total operating costs and fixed
charges
9,536.80
7,063.81
3,302.01
57,038.93
19,947.70
Net surplus
1,111.66
570.93
1,597.75
2,864.34
Net loss
307.97
Number of Consumers
Domestic service
219
71
8
126
40
3
62
24
1
1,165
191
16
420
Commercial light service
135
Power service
12
Total
298
169
87
1,372
567
934
HYDRO-ELECTRIC POWER COMMISSION
363
4< B"— Continued
Hydro Municipalities for Year Ended December 31, 1933
Tillson-
burg
3,351
Toronto
626,674
Toronto
Twp
Trafalgar
Twp.
Area No. 1
Trafalgar
Twp.
Area No. 2
Walkerville
10,681
Wallaceburg
4,343
$ c
14,962.86
11,687.36
$ c.
3.747,121.17
2,873,701.12
3,167,430.03
1.307,218.35
531,411.66
$ c.
58,575.37
13,743.10
6,862.46
$ c.
14,152.49
640.62
520.19
$ c.
4,967.94
$ c.
104,317.38
29,322.93
127,701.63
$ c.
18,859.03
10,687.00
10,821.20
49,402.59
834.59
1,913.90
4,336.51
4,975.20
11,739.96
4,167.00
9.36
485 . 15
268,812.13
1,460.57
222.18
96.87
2,182.57
719.62
43,137.03
11,895,694.46
85,616.70
15,535.48
5,064.81
275,264.47
85,749.14
27,345.49
889.99
6,493,300.17
217,852.14
247,239.28
350,632.98
37,083.99
101,462.78
295,659.39
133,653.43
178,555.92
344,206.94
365,072.53
*97,936.46
50,054.65
7,888.00
2,272. 2i5
203,458.83
5,385.14
1,739.13
3,890.69
397.92
2,728.77
2,759.58
2,578.80
4,220.93
6,074.17
10,297.39
7,614.83
2.075.91
8,673.39
15,269.85
16,322.00
61,125.39
248 . 00
3,022.14
267.53
3,706.18
468 . 63
402.28
2,134.48
535.72
1,914.39
264.18
68.70
713.77
44.95
39.75
549.98
623.94
836.01
836.17
756.15
3,096.58
4,607.09
931.32
1,504.60
3,845.61
5,133.95
8,390.00
2,201.19
3,509.20
355.47
411.82
1,414.13
136.18
223.20
744.89
928.70
1,124.00
549.27
26.98
2,341.53
1,398 69
740.73
513.58
1,032.76
1,461,031.47
1,237,415.80
823,554.56
2,740.83
526.54
2,730.08
2,747.56
3,199.00
139.33
293 . 00
4,725.00
88.15
42,301.57
12,387,398.67
82,764.83
14,662.28
4,203.76
293,487.33
82,686.41
835.46
2,851.87
873.20
861.05
3,062.73
491,704.21
18,222.86
887
223
155,870
25,980
5,099
1,875
188
23
300
2
9
136
2.367
317
94
1,020
223
30
29
1,140
186,949
2,086
311
136
2,778
1,272
Includes $25,817.88 York Twp. debenture charges.
364
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Detailed Operating Reports of Electrical Departments of
NIAGARA
SYSTEM— Continued
Municipality
Wardsville
214
Waterdown
924
Waterford
1,168
Waterloo
8,563
Watford
Population
956
Earnings
Domestic service
$ c.
1,124.76
1,075.78
$ c.
5,645.12
1,696.40
1,468.02
192.52
901.50
$ c.
6,575.26
1,766.76
4,146.55
276.32
1,608.00
$ c.
58,827.49
20,814.44
24,058.94
3,505.88
7,499.04
320.62
149.94
$ c.
6,682.44
Commercial light service
3,237.14
Commercial power service
2,356 16
Municipal power
435.37
Street lighting
700.00
1,344.96
Merchandise
Miscellaneous
55.84
11.60
260.49
335.79
Total earnings
2,956.38
9,915.16
14,633.38
115,176.35
14,391.86
Expenses
Power purchased . .
1,936.53
6,493.32
11,933.09
91,535.77
1,401.68
1,377.44
3,743.64
33.60
1,035.65
9,303 . 14
Substation operation
Substation maintenance
Distribution system, operation and
maintenance
Line transformer maintenance
51.30
307.05
49.65
110.96
331.30
742.05
Meter maintenance
42.55
138.48
Consumers' premises expenses
Street lighting, operation and main-
tenance
36.30
60.01
174.46
762.00
136.02
Promotion of business
Billing and collecting
566.49
145.52
51.62
576.00
398.68
26.93
2,035.20
3,383.28
560.44
984.87
2,881.88
4,892.31
8,762.00
128.00
501.72
General office, salaries and expenses. .
Undistributed expenses
182.83
539.82
60.06
Truck operation and maintenance. . .
129.36
Interest
299 . 17
412.83
235 . 00
10.50
124.17
Sinking fund and principal payments
on debentures
712 62
Depreciation
791.00
966 . 00
752.00
Other reserves
Total operating costs and fixed
charges
3,153.96
8,586.12
14,449.01
123,517.76
13,139.44
Net surplus
1,329.04
184.37
1,252.42
Net loss
197.58
8,341.41
Number of Consumers
Domestic service
47
21
218
33
7
306
73
11
1,850
249
77
284
Commercial light service
76
Power service
5
Total
68
258
390
2,176
365
1934
HYDRO-ELECTRIC POWER COMMISSION
365
"B"— Continued
Hydro Municipalities for Year Ended December 31, 1933
Welland
10,668
Wellesley
P.V.
West Lome
814
Weston
4,736
Wheat ley
724
Windsor
65,565
Wood-
bridge
744
Woodstock
10,956
$ c.
49,514.12
28,463.15
60,726.86
2,397.93
$ c.
2,706.26
1,527.81
1,773.00
$ c.
3,197.04
1,483.82
1,277.99
$ c.
39,599.41
9,376.18
31,984.50
588.46
7,610.13
$ c.
4,427.83
2,717.93
1,599.90
461.86
1,355.25
$ c.
503,381.88
225,233.06
170,277.85
11,734.67
76,109.88
$ c.
6,370 89
1,632.47
4,670.69
410.44
900.00
$ c.
72,772.34
37,336.87
46,357.30
2,846.43
10,559.01
1,841. 15
720.00
1,010.00
8,013.40
3,384.77
12.76
55.57
899.56
92.66
21.48
3,554.32
156,886.99
6,739.83
7,024.42
90,058.24
10,655.43
986,737.34
14,005.97
170,880.66
94,636.78
4,898.27
5,208.81
3,970.10
68,789.37
6,401.77
589,905.81
15,910.88
3,473.27
12,577.85
1,844.42
12,278.03
22,628.07
13,375.44
18,016.56
31,162.17
27,751.66
17,147.22
14,675.38
65,640.56
85,361.15
64,790.00
10,143.24
131,319.41
2,724.48
90.61
169.36
4,658.02
332.01
830.30
83.45
7,144.69
132.46
31.44
150.33
498.49
24.70
146.44
418.69
5,138.27
549.12
2,985.44
52.40
32.16
1,273.79
263.90
1,121.71
36.84
117.24
961.09
275.56
151.28
2,197.71
267.30
4,103.83
464.70
169.62
15.00
641.10
2,930.44
582.05
454.68
2,216.03
3,016.95
4,830.00
328.18
193.40
43.73
3,716 79
9,018.64
943.33
431.05
26.03
563.59
4,999.07
1,651.43
1,597.40
817 35
14,131.55
9,991.62
12,213.53
138.84
517.94
313.00
328.57
257.07
593.00
485 . 15
603.65
588.00
480.66
291.59
800.00
3,424.55
2,682.05
11,775.00
163,273.76
6,756.35
6,097.79
90,411.40
9,589.07
996,538.47
12,849.05
172,619.77
926.63
1,066.36
1,156.92
6,386.77
16.52
353.16
9,801.13
1,739.11
2,271
438
83
121
44
5
187
49
4
1,248
179
30
171
57
4
14,605
2,263
318
244
50
6
2,904
443
86
2,792
170
240
1,457
232
17,186
300
3,433
366
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Detailed Operating Reports of Electrical Departments of
NIAGARA
SYSTEM— Concluded
Municipality
Wyoming
482
*York Twp.
Zurich
P.V.
NIAGARA
Population
SYSTEM
SUMMARY
Earnings
Domestic service
$ c.
2,647.88
1,582.19
152.10
$ c.
558,465.55
64,625.08
89,734.45
$ c.
3,176.37
1,860.84
$ c.
9,263,031.01
4,987,219.71
7,326,323.77
1,646,884.64
1,389,025.47
9,301 81
402,652.28
Commercial light service
Commercial power service
Municipal power
Street lighting
765.00
49,614.79
693 . 00
Merchandise
Miscellaneous
15.28
17,073.89
117.72
Total earnings
5,162.45
779,513.76
5,847.93
25,024,438 69
Expenses
Power purchased
3,201.18
379,460.71
4,601.35
15,413,215.29
404,570.48
Substation operation
Substation maintenance
27,860.54
20,607.93
3,984.68
6,128.79
25,117.30
8,066.62
3,031.51
37,034.11
34,822.33
35,912.94
281,366.35
Distribution system, operation and
maintenance
92.89
232.42
722,383.72
Line transformer maintenance
71,396.55
Meter maintenance
67.55
230,149.55
Consumers' premises expenses
353,539.08
Street lighting, operation and main-
tenance
58.11
80.10
271,828.92
Promotion of business. .
244,030.17
Billing and collecting
166 . 00
167.87
183.94
92.69
20.11
673,185.33
General office, salaries and expenses . .
Undistributed expenses
740,249.97
268,362.00
Truck operation and maintenance . . .
84,066 . 24
Interest
150.56
750.03
385.00
199,599.83
21,824.38
20,428.00
215.83
174.67
372.00
2,179,869.71
Sinking fund and principal payments
on debentures
2,108,108.41
Depreciation
1,604,015.63
Other reserves
26,493.60
Total operating costs and fixed
charges
4,971.64
823,879.67
6,040.66
25,676,831.00
Net surplus
190.81
Net loss
44,365.91
192.73
652,392.31
Number of Consumers
Domestic service
132
50
2
19,397
1,037
150
124
46
366,817
Commercial light service
58,040
Power service . .
10,590
Total
184
20,584
170
435,447
*For year ended December 31, 1932. Included in Toronto figures. Not added in Summary.
934
HYDRO-ELECTRIC POWER COMMISSION
367
"B"— Continued
Hydro Municipalities for Year Ended December 31, 1933
GEORGIAN BAY
SYSTEM
Alliston
1,379
Arthur
1,037
Barrie
7,455
Beaverton
960
Beeton
584
Bradford
1,009
Brechin
P.V.
Cannington
851
$ c.
8,513.19
4,492.67
1,665.75
812.96
$ c
4,569.26
3,636.14
1,636.55
576.53
1,748.00
$ c.
52,465.38
29,741.26
15,417.24
983.33
5,961.25
$ c.
6,038.34
2,354.80
1,080.55
$ c
3.594.5C
2,482. 4C
1,852.91
$ c
6,341.25
3,006.67
2,654.76
336.89
1,273.00
60.43
60.67
$ c
971.23
1,074.32
1,077.29
$ c.
5,185.51
2,337.93
619.89
2,070.00
1,286.52
1,185.00
576.00
1,022.00
28.64
1,302.38
793 . 85
9.66
28.53
80.75
17,583.21
12,166.48
105,870.84
11,554.06
9,124.47
13,733.67
3,727.37
9,246.08
11,574.06
9,561.78
76,201.02
894.47
7,686.41
7,116.40
8,416.51
2,641.63
6,682.04
623.40
553.34
2,870.39
493 . 80
1,485.18
991.21
42.63
225.49
302.50
586.78
339.40
89.55
1,020.39
169.02
193.93
57.23
42.09
149.70
10.60
822.79
3,102.46
1,122.64
1,000.07
583.59
3,048.82
2,691.38
7,023.00
300.00
634.56
76.17
254.61
135.55
85.81
378.13
607 . 09
408.38
143.77
568.93
1,765.08
1,390.41
1,332.00
1,155.08
720.71
906 . 00
366.62
580.34
1,101.00
534.07
447.01
579.00
1,176.50
836.30
825.00
219.05
98.29
138.00
505.57
608.17
652.00
18,068.50
13,364.59
101,837.21
11,501.69
9,321.42
12,502.37
3,585.33
9,763.79
4,033.63
52.37
1,231.30
142.04
485 . 29
1,198.11
196.95
517.71
351
201
16
185
86
4
2,011
407
45
303
63
9
124
37
5
223
63
8
42
28
4
246
71
10
568
275
2,463
375
166
294
74
327
368
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Detailed Operating Reports of Electrical Departments of
GEORGAIN BAY
SYSTEM— Continued
Municipality
Population
Chatsworth
272
Chesley
1,789
Coldwater
626
Colling-
wood
5,788
Cooks-
town
P.V.
Earnings
Domestic service
$ c.
1,590.06
1,304.24
583.08
$ c.
8,902.79
4,106.77
8,451.38
991.04
1,596.00
5.02
664.48
$ c.
2,884.70
1,746.74
2,557.43
$ c.
26,122.58
9,951.70
16,342.67
1,895.68
3,013.33
$ c.
2,479.81
Commercial light service
1,264.87
Commercial power service
911.92
Municipal power
Street lighting
492.00
571.00
1,008.00
Merchandise
Miscellaneous
89.84
209.01
1,515.88
46.37
Total earnings
4,059.22
24,717.48
7,968.88
58,841.84
5,710.97
Expenses
Power purchased
Substation operation
2,565.47
18,031.74
6,811.92
49,999 . 25
2,686.76
Substation maintenance
39.50
1,789.46
70.59
677.75
Distribution system, operation and
maintenance
189.73
672.90
298 . 24
168.78
Line transformer maintenance
Meter maintenance
160.25
Consumers' premises expenses . .
Street lighting, operation and main-
tenance
59.22
188.20
63.00
239.71
6.22
2,866.05
2,913.18
616.91
318.33
300.00
86.48
Promotion of business
Billing and collecting
386.41
612.45
122.07
24.50
404.81
1,934.61
1,206.00
General office, salaries and expenses. .
Undistributed expenses . .
327.53
497 . 22
270.22
Truck operation and maintenance. . .
Interest.
282.18
216.19
262.00
217.73
267.27
531.00
444 . 62
Sinking fund and principal payments
on debentures . .
282.86
Depreciation ....
3,750.00
503.00
Other reserves
Total operating costs and fixed
charges
3,902.32
23,743.94
8,686.38
63,586.95
4,442.72
Net surplus
156.90
973.54
1,268.25
Net loss
717.50
4,745.11
Number of Consumers
Domestic service
73
29
1
420
97
19
131
54
4
1,420
269
53
96
Commercial light service
27
Power service
5
Total
103
536
189
1,742
128
1934
HYDRO-ELECTRIC POWER COMMISSION
369
"B"— Continued
Hydro Municipalities for Year Ended December 31, 1933
Creemore
587
Dundalk
647
Durham
1,800
Elmvale
P.V.
Elm wood
P.V.
Flesherton
491
Grand
Valley
587
Graven -
hurst
1,830
$ c.
3,579.49
1,808.96
1,102.80
$ c.
2,604.62
2,200.70
2,240.17
$ c.
6,477.31
4,139.84
5,857.92
759.79
1,935.00
$ c.
2,673.02
1,728.30
2,618.79
140.33
662.31
$ c.
1,185.37
586.45
1,339.14
$ c.
2,686.74
1,768.58
226.29
' $ c.
3,467.61
1,799.23
1,975.40
$ c.
8,580.86
6,087.91
7,202.34
575.67
673.63
1,220.00
529.00
621.00
936.00
2,096.24
7.00
165.00
772.47
86.34
36.96
30.54
138.21
7,171.88
8,430.49
19,942.33
7,909.09
3,676.92
5,333.15
8,316.45
24,543.02
5,789.05
6,224.88
15,726.37
6,373.35
2,541.79
3,547.92
5,796.19
16,208.46
200.17
627.53
- 795.45
617.01
12.50
36.47
117.92
1,227.17
67.78
28.65
17.35
138.03
62.84
124.31
166.19
30.18
13.10
26.55
66.00
572.91
10.47
1,043.82
494.55
248.10
267.18
344.40
1,296.91
1,108.00
210.00
53.21
23.50
431.11
252.65
611.30
194.93
384.97
529.83
1,455.67
275.96
255.67
129.91
504.36
387.00
67.07
356.35
432.00
175.81
279.55
600.00
215.68
426.08
238.00
398.72
264.97
336.00
213.48
759.64
523.00
722.51
2,088.21
1,700.00
225.00
7,325.98
8,443.44
21,519.62
8,379.96
3,642.08
4,995.60
8,006.06
25,378.95
34.84
337.55
310.39
154.10
12 95
1,577.29
470.87
835.93
157
52
3
157
69
4
422
109
11
150
59
8
58
19
1
139
48
2
156
48
4
464
115
12
212
230
542
217
78
189
208
591
370
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Detailed Operating Reports of Electrical Departments of
GEORGIAN BAY
SYSTEM— Continued
Municipality
Hanover
3,036
Holstein
P.V.
Huntsville
2,507
Kincardine
2,429
Kirkfield
Population
P.V.
Earnings
Domestic service
$ c.
18,407.63
6,627.47
17,684.10
309.97
3,488.16
$ c.
1,479.27
570.60
238.59
"490.00
$ c.
10,973.86
7,418.16
11,515.00
1,400.00
2,675.00
$ c.
13,824.32
6,956.57
9,058.53
1,444.90
4,022.50
$ c.
749.21
Commercial light service
1,156.47
Commercial power service
Municipal power
Street lighting
460.00
Merchandise
Miscellaneous
1,540.64
682.94
30.18
Total earnings
48,057.97
2,778.46
34,664.96
35,337.00
2,365.68
Expenses
Power purchased
31,066.93
1,955.95
29,980.04
25,823.72
336.94
1,423.29
Substation operation
Substation maintenance
Distribution system, operation and
maintenance
1,776.72
36.37
114.89
51.05
2,322.42
19.45
49.10
1,258.69
204.62
Line transformer maintenance
Meter maintenance ....
Consumers' premises expenses
112.01
263 . 10
Street lighting, operation and main-
tenance
174.81
14.92
230.71
96.10
507.34
1,241.20
719.78
186.31
206 . 88
686.36
1,080.00
3.48
Promotion of business
Billing and collecting
1,097.39
634.21
491.15
141.94
2,386.90
5,282.60
3,233.00
" 169 '. 24
678.44
567.61
377.31
259.97
2,114.88
3,167.80
2,075.00
General office, salaries and expenses . .
Undistributed expenses
35.05
Truck operation and maintenance. . .
Interest
214.07
213.79
109 . 00
243.62
Sinking fund and principal payments
on debentures
347.88
Depreciation
206 . 00
Other reserves
Total operating costs and fixed
charges
46,436.91
2,728.02
37,325.69
37,035.47
2,463.94
Net surplus . .
1,621.06
50.44
Net loss
2,660.73
1,698.47
98.26
Number of Consumers
Domestic service
726
119
20
54
18
1
556
123
9
596
120
19
27
Commercial light service
20
Power service
Total
865
73
688
735
47
934
HYDRO-ELECTRIC POWER COMMISSION
371
"B" -Continued
Hydro Municipalities for Year Ended December 31, 1933
Lucknow
1,082
Markdale
774
Meaford
2,707
Midland
6,808
Mildmay
694
Mount
Forest
1,821
Neustadt
465
Orangeville
2,785
$ c.
6,845.31
2,998.23
3,499.49
517.52
$ c.
3,571.87
2,580.48
1,048.02
81.00
900 . 00
$ c.
12,262.19
6,475.28
3,878.90
761.52
3,219.19
2.58
765.66
$ c.
35,287.78
13,714.77
47,445.51
3,029.05
6,175.84
$ c.
2,967.88
2,024.23
719.27
$ c.
7,571.59
5,190.17
3,040.59
1,214.91
2,370.00
$ c.
2,019.90
1,357.97
63.33
$ c.
14,312.27
8,697.09
6,926.65
1,264.70
1,522.50
659.56
975 . 00
3,760.20
16.61
187.01
21.06
262.75
168.65
15,570.06
8,181.37
27,365.32
105,652.95
6,392.00
19,650.01
4,416.20
35,146.17
10,946.31
5,784.99
17,537.97
80,691.58
1,993.84
207.58
2,373.26
78.54
781.45
3,054.84
15,632.99
3,441.78
26,032.43
363.49
22.44
953.55
34.50
40.07
149.64
469.98
28.92
1,315.31
229.09
159.45
49.55
10 70
122.76
117.48
209.00
676.98
875.21
2,179.46
2,409.97
2,008.55
315.28
2,555.03
5,449.28
9,512.00
42.80
320.62
69.95
485.42
579.35
1,749.10
468.22
121.52
1,971.51
1,018.24
1,340.00
817.89
386.50
119.25
39.05
713.66
635.63
1,310.00
1,418.12
876.03
439.21
375.06
205.61
35.40
101 02
739.41
962.87
732.00
375.21
306.55
576.00
408.86
408.27
206.00
921.48
986.86
560.00
656.87
2,307.85
1,916.00
14,742.87
7,621.88
26,023.03
112,108.01
4,874.56
20,605.02
6,214.60
34,328.67
827.19
559.49
1,342.29
1,517.44
817.50
6,455.06
955.01
1,798.40
252
79
7
187
79
10
638
138
17
1,564
227
55
140
47
2
447
160
96
28
2
654
161
27
338
276
793
1,846
189
618
126
842
372
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Detailed Operating Reports of Electrical Departments of
GEORGIAN BAY
SYSTEM— Continued
Municipality
Owen
Sound
12,803
Paisley
732
Penetang-
uishene
4,046
Port
Elgin
1,230
Port
Population
McNicoll
928
Earnings
Domestic service
$ c.
60,161.55
33,647.11
37,592.84
$ c.
3,937.95
2,679.61
1,155.09
$ c.
11,560.03
4,471.57
10,183.08
1,752.93
2,149.00
17.81
77.30
$ c.
8,046.31
4,123.07
3,400.92
886.65
2,103.79
$ c.
3,643.06
801 37
Commercial light service
Commercial power service
Municipal power
Street lighting
11,181.23
279.45
131.16
1,408.00
927 50
Merchandise
Miscellaneous
143.99
315.46
Total earnings
142,993.34
9,324.64
30,211.72
18,876.20
5,371.93
Expenses
Power purchased
Substation operation
106,952.41
4,695.16
6,583.66
21,327.95
643.51
103.71
1,438.26
106.25
222.53
8,730.36
3,295.61
Substation maintenance
Distribution system, operation and
maintenance
5,903.00
548.54
1,059.77
128.90
942.49
383.69
Line transformer maintenance
Meter maintenance
44.54
Consumers' premises expenses
Street lighting, operation and main-
tenance
Promotion of business. . . . . .
2,614.07
105.84
248 . 20
217.80
120.84
Billing and collecting
5,216.40
5,646.34
2,647.53
730.57
516.18
942.21
686 . 68
270.72
142.90
1,122.97
1,655.05
2,817.00
689.37
86.98
138.58
272.95
1,981.31
1,400.40
826.00
General office, salaries and expenses. .
Undistributed expenses
472.50
120.75
Truck operation and maintenance. . .
Interest . .
618.43
742.95
506.00
186.79
Sinking fund and principal payments
on debentures . .
484 . 43
Depreciation
6,920.00
390.00
Other reserves
Total operating costs and fixed
charges
143,449.97
9,158.28
31,727.94
15,330.78
4,982.11
Net surplus
166.36
3,545.42
389.82
Net loss
456.63
1,516.22
Number of Consumers
Domestic service
3,257
576
115
186
55
4
599
99
27
373
86
8
197
Commercial light service
31
Power service
Total
3,948
245
72.5
467
228
1934
HYDRO-ELECTRIC POWER COMMISSION
373
"B"— Continued
Hydro Municipalities for Year Ended December 31, 1933
Port Perry
1,130
Priceville
P.V.
Ripley
451
Rosseau
251
Shelburne
1,064
South-
ampton
1,520
Stayner
1,042
Sunder-
land
P.V.
$ c.
6,660.96
2,805.22
2,528.58
$ c.
675.10
332.43
$ c.
3,363.35
1,858.53
$ c.
2,871.74
927.90
$ c.
5,384.95
3,309.71
1,591.58
578.43
960 . 00
$ c.
8,144.39
3,487.74
2,137.68
1,231.34
2,106.92
$ c.
4,391.43
2,642.06
2,375.56
$ c.
2,335.55
1,699.71
55.85
372.11
1,500.00
560.00
1,266.00
1,240.00
1,224.00
706.67
894 . 65
11.55
4.49
141.67
233.65
150.44
328.64
50.00
14,761.52
1,579.08
6,492.37
5,181.31
12,058.32
17,258.51
10,961.69
4,847.78
9,873.21
1,139.68
4,204.77
3,550.01
9,554.83
8,228.69
8,245.44
3,473.99
901.67
15.24
' 35.50
206.93
45
925.20
1,109.33
2.10
50.85
549.12
170.22
1.82
51.87
100.25
21.76
66.72
24.69
148.14
142.22
21.37
131.81
7.52
15.75
553.89
74.74
863.40
233.93
235.85
307.68
1,428.87
1,100.31
701.00
566.06
112.57
72.92
820.37
46.61
419.48
321.77
15.00
954.68
747.50
454.94
328.21
177.00
648 . 74
381.78
426.00
956.15
349.69
1,321.85
945 . 00
176.21
1,085.53
806 . 00
222.84
318.58
821.00
288 . 00
278.00
14,233.68
2,183.44
6,182.99
5,181.31
13,778.89
14,410.15
11,756.07
4,806.77
527.84
604.36
309.38
2,848.36
41.01
1,720.57
794.38
300
75
10
31
12
128
44
61
21
285
83
11
384
83
13
257
S3
12
112
42
1
385
43
172
82
379
480
352
155
374
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Detailed Operating Reports of Electrical Departments of
GEORGIAN BAY
SYSTEM— Concluded
Municipality
Tara
491
Tees water
805
Thornton
P.V.
Tottenham
546
Uxbridge
1,506
Population
Earnings
Domestic service
$ c.
2,632.36
1,306.32
690.33
$ c.
4,642.20
2,219.12
939 . 09
180.00
1,402.00
$ c.
1,151.90
637.95
243 . 14
$ c.
3,227.06
2,100.62
166.00
194.99
1,225.08
$ c.
8,019.21
Commercial light service
3,255.12
Commercial power service
931.13
Municipal power
Street lighting
1,260.00
880.00
1,743.00
Merchandise
Miscellaneous
6.04
190.45
2.79
3.45
405 . 78
Total earnings
5,895.05
9,572.86
2,915.78
6,917.20
14,354.24
Expenses
Power purchased
3,432.35
6,115.52
1,481.77
5,087.62
10,902.64
Substation maintenance
Distribution system, operation and
maintenance
175.70
62.41
46.75
322.35
585.46
Line transformer maintenance
Meter maintenance
Consumers' premises expenses
Street lighting, operation and main-
tenance
37.10
69.55
17.32
105.46
229.30
Promotion of business
Billing and collecting
General office, salaries and expenses. .
Undistributed expenses
486.60
543 . 08
81.93
192.20
785 . 19
Truck operation and maintenance. . .
Interest
354.98
942.80
520.00
993 . 03
1,132.80
690.00
306.86
425.02
307.00
445.71
383.81
410.00
772.92
Sinking fund and principal payments
on debentures
973.67
Depreciation
665 . 00
Other reserves
Total operating costs and fixed
charges
5,949.53
9,606.39
2,666.65
6,947.15
14,914.18
Net surplus
249 . 13
Net loss
54 . 48
33.53
29.95
559.94
Number of Consumers
Domestic service
127
36
4
195
55
7
55
18
4
128
54
4
354
Commercial light service
91
Power service
10
Total
167
257
77
186
455
1934
HYDRO-ELECTRIC POWER COMMISSION
375
"B"— Continued
Hydro Municipalities for Year Ended December 31, 1933
Victoria
Harbor
1,171
Walker-
ton
2,340
Waubau-
shene
P.V.
Wiarton
1,911
Winder-
mere
135
Wingham
1,842
Wood-
ville
414
GEORGIAN
BAY
SYSTEM
SUMMARY
$ c.
2,894.43
839 . 09
47.34
$ c.
15,041.12
7,683.67
4,262.46
657.15
2,369.55
27.87
85.90
$ c.
2,221.71
630.34
604 . 89
98.29
405 . 00
$ c.
8,800.93
5,782.47
1,820.13
1,403.92
2,300.00
$ c.
2,241.87
1,095.71
$ c.
12,512.87
6,933.68
8,308.52
480.35
3,423.00
669.15
470.69
$' c.
2,291.30
1,068.90
770.18
$ c.
478,039.49
249,726.99
262,336.64
124.20
25,056.15
702.00
455.00
532.00
"298.83
105,222.97
1,078.92
1.10
110.56
10.13
13,794.19
4,608.16
30,127.72
4,070.25
20,107.45
3,802.71
32,798.26
4,961.21
1,135,255.35
3,112.17
16,105.10
2,153.97
14,375.20
2,026.84
16,384.56
1,746.47
3,193.34
805,087.51
10,310.39
350.79
50.09
1,885.83
70.00
112.30
113.17
408.39
168.92
2,549.36
246.32
43,563.46
1,528.37
126.45
295 . 20
5,842.45
124.53
116.06
203.80
75.79
212.13
29.67
355.92
34.45
11,862.35
998.60
1,468.08
1,117.42
161.88
285.56
3,054.73
2,000.55
1,324.00
990.90
1 279.86
107.50
92.77
1,658.63
1,131.07
700.00
159.41
29.18
36.75
577.04
714.42
451.76
139.18
2,459.05
3,901.39
2,797.00
"32l'03
28,933.76
353.29
324.35
35,441.35
11,051.55
4,499.95
81.75
463.21
390.00
48.94
256.21
264 . 00
*719.36
282.00
187.88
231.73
223.00
46,897.73
59,232.44
71,460.00
525.00
4,566.57
27,789.25
3,236.43
20,082.90
3,452.13
32,371.35
4,437.75
1,137,710.23
41.59
2,338.47
833.82
24.55
350.58
426.91
523.46
2,454.88
167
28
2
535
134
17
134
25
3
349
103
13
48
9
504
143
24
110
31
2
22,141
5,287
699
197
686
162
465
57
671
143
28,127
'Includes debenture accrual.
376
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Detailed Operating Reports of Electrical Departments of
EASTERN ONTARIO
SYSTEM
Municipality ....
Alexandria
2,340
Apple Hill
P.V.
Athens
582
Bath
350
Belleville
Population
14,059
Earnings
Domestic service
$ c.
7,390.51
4,173.80
3,174.90
1,634.41
2,640.00
$ c.
1,080.88
827.60
279.49
$ c.
3,966.74
1,813.42
1,127.76
$ c.
1,441.86
718.97
$ c.
76,682.94
Commercial light service
48,107.35
Commercial power service
34,529.14
Municipal power
7,709.49
Street lighting. .
559.75
1,250.00
714.00
11,655.86
Merchandise
544.70
Miscellaneous
355.93
3. 38
19.19
16.03
885.68
Total earnings
19,369.55
2,751.10
8,177.11
2,890.86
180,115.16
Expenses
Power purchased
12,609.86
1,726.10
4,738.92
2,105.43
128,674.13
Substation operation
Substation maintenance
Distribution system, operation and
maintenance
885 . 29
122.42
152.13
3.03
299.66
52.10
87.12
2.24
19.79
8.18
3,914.42
Line transformer maintenance
288.26
Meter maintenance
2,889.51
Consumers' premises expenses
325.52
Street lighting, operation and main-
tenance
58.01
108.87
1,399.56
Promotion of business
1,185.78
Billing and collecting
912.85
400.91
105.51
4,245.76
General office, salaries and expenses. .
Undistributed expenses
234.39
174.62
15.00
131.73
7,098.63
1,762.82
Truck operation and maintenance. . .
214.16
Interest
Sinking fund and principal payments
on debentures ...
1,466.06
2,498.40
1,298.00
222.47
303.95
159.00
674.09
497.41
437.00
485.30
215.09
164.00
1,701.00
6,000.00
Depreciation
5,251.00
Other reserves
Total operating costs and fixed
charges
20,754.12
2,756.02
6,755.06
3,109.73
164,950.55
Net surplus
1,422.05
218.87
15,164.61
Net loss . .
1,384.57
4.92
Number of Consumers
Domestic service
295
92
14
46
18
1
140
50
31
16
3,004
Commercial light service
Power service
555
90
Total
401
65
191
47
3,649
1934
HYDRO-ELECTRIC POWER COMMISSION
377
4 'B"- Continued
Hydro Municipalities for Year Ended December 31, 1933
Bloom field
614
Bowman-
ville
3,641
Brighton
1,413
Brockville
9,615
Cardinal
1,305
Carleton
Place
4,272
Chesterville
950
$ c.
2,713.31
807 . 79
497 . 13
$ c.
30,135.04
10,239.80
40,064 . 74
$ c.
10,102.13
4,619.79
2,051.65
$ c.
45,903.86
25,015.27
30,457.81
5,566.61
8,772.50
$ c.
6,257.90
1,943.40
551.64
$ c.
18,946.89
9,355.65
23,803.35
1,930.94
4,385.00
$ c.
5,396.47
2,298 21
2,562.57
720.00
4,057.17
1,644.00
1,066.00
1,032.00
241.05
5.46
620.16
77.59
6,450.70
4.44
2,203.81
506 . 08
4,743.69
85,116.91
18,495.16
122,166.75
9,823.38
60,625.64
12,036.38
4,139.16
63,015.45
10,233.57
75,024.19
5,415.00
498 . 09
1,793.65
418.09
1,957.13
5,566.26
38,341.57
8,042.22
171.79
1,765.85
65.30
176.60
63.90
2,291.59
288.34
472.34
4.10
610.53
8.35
1,943.55
2,515.67
979.05
2,722.31
140.00
262.53
48.95
182.99
64.96
8 15,. 02
1,487.67
733.98
350.94
1,140.51
851.76
574.00
823.14
45.00
4.80
1.48
176.85
977.58
157.26
100.00
1,871.14
198.92
2,159.94
5,082.23
1,928.91
608.87
3,935.46
7,249.18
8,191.00
298.48
180.00
1,557.25
3,373.66
276.02
648.34
2,684.61
2,409.68
1,974.00
500.00
409.75
201.76
499 . 27
413.89
486.48
403.82
486.00
2,965.14
2,309.30
1,493.00
703.50
500.13
329.00
106.24
190.90
597.00
6,038.38
78,896.41
19,609.19
116,331.80
8,649.43
54,243.15
10,917.58
6,220.50
5,834.95
1,173.95
6,382.49
1 118 80
1,294.69
1,114.03
148
26
4
1,045
173
29
537
95
9
2,541
438
67
286
50
2
938
178
18
227
65
3
178
1,247
641
3,046
338
1,134
295
378
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Detailed Operating Reports of Electrical Departments of
EASTERN ONTARIO
SYSTEM— Contin ued
Municipality
Cobourg
5,619
Colborne*
977
Deseronto
1,418
Finch
383
Hastings
707
Population
Earnings
Domestic service. .
$ c.
30,913.56
18,424.66
22,556.07
5,388.15
5,584.04
$ c.
4,517.68
3,112.69
357.94
233.32
1,287.00
128.24
181.67
$ c.
6,416.69
2,254.49
1,171.51
856.70
1,791.96
28.30
228.2-4
$ c.
1,941.99
1,549.09
700.39
$ c.
3,997 82
Commercial light service
1,684.61
Commercial power service
759 66
Municipal power
Street lighting
502.50
1,550.92
Merchandise
Miscellaneous
1,120.51
122.96
236.43
Total earnings.
83,986.99
9,818.54
12,747.89
4,816.93
8,229.44
Expenses
Power purchased
54,650.04
4,171.90
7,090.74
2,686.18
3,443.48
Substation operation
Substation maintenance
Distribution system, operation and
maintenance
1,922.74
613.81
591.35
210.47
684.56
5.63
2,404.41
3,940.15
1,594.58
124.75
4,763.05
3,291.15
2,207.00
867.06
60.32
72.79
1,716.77
8.96
231.62
93.65
152.28
Line transformer maintenance
Meter maintenance
8.39
Consumers' premises expenses
Street lighting, operation and main-
tenance
108.69
245.36
28.90
85.08
Promotion of business . .
Billing and collecting
' 1,237.79
40.34
220.66
940.11
304.93
701.75
82.60
General office, salaries and expenses. .
Undistributed expenses
213.48
388.46
27.00
Truck operation and maintenance. . .
Interest. . .
574.36
487.88
350.00
374.58
254.64
253.00
1,155.40
Sinking fund and principal payments
on debentures
635.39
Depreciation
188.00
419.00
Other reserves
Total operating costs and fixed
charges
77,003.69
7,907.66
11,794.97
3,904.43
6,314.48
Net surplus
6,983.30
1,910.88
952.92
912.50
1,914.96
Net loss
Number of Consumers
Domestic service
1,114
141
45
218
79
3
291
66
11
78
31
1
166
Commercial light service
49
Power service
5
Total
1,300
300
368
110
220
*Eleven months operation.
1934
HYDRO-ELECTRIC POWER COMMISSION
379
1 'B"— Continued
Hydro Municipalities for Year Ended December 31, 1933
Havelock
1,096
Kemptville
1,227
Kingston
23,260
La Icefield
1,303
Lanark
636
Lancaster
601
Lindsay
7,109
$ c.
6,089.60
2,087.16
2,881.48
$ c.
7,000.28
4,387.41
4,620.72
$ c.
108,782.64
72,441.72
87,493.96
10,776.04
25,486.08
$ c.
6,425 . 25
3,463.55
1,826.60
$ c.
2,792.36
1,201.42
$ c.
2,016.86
1,677.89
$ c.
37,863.94
22,212.24
23,502.85
2,766.94
1,508.00
1,830.00
1,836.00
592.00
1,496.50
8,172.90
363 . 29
1,013.48
5,093.99
709.52
104.92
2,838.90
12,929.53
18,851.89
310,074.43
14,260.92
4,690.70
5,191.25
97,357.77
7,263.50
10,635.37
133,259 80
5,155.05
3,222.67
18,450.85
852.15
5,377.77
2,044.74
9,335.17
216.79
7,519.97
13,008.98
12,678.45
3,319.30
7,912.95
11,142.78
19,218.00
25,744.76
10,133.61
3,392.60
3,377.46
68,252.96
751.52
1,594.48
44.46
296.74
886.32
317.43
105.50
2,860.38
493 . 18
42.63
96.57
480.86
521.69
121.00
138.46
37.24
969.33
510.82
113.26
57.09
27.34
1,184.90
595.74
611.09
200.85
2,610.25
358.46
304 . 23
301.90
6,405.06
1,446.13
183.66
362.41
1,153.09
636.30
897.00
217.20
1,098.33
1,775.58
843 . 00
1,766.00
825.76
1,108.00
234.54
464.45
254.00
437.17
711.11
277.00
5,470.74
4,778.81
3,427.00
12,395.05
17,275.70
278,460.18
16,283.26
5,120.91
5,237.48
98,149.16
534.48
1,576.19
31,614.25
2,022.34
430.21
46.23
791.39
281
64
3
318
S3
7
5,620
878
143
309
69
6
150
36
78
36
1,830
334
76
348
408
6,641
384
186
114
2,240
380
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Detailed Operating Reports of Electrical Departments of
EASTERN ONTARIO
SYSTEM— Continued
Municipality
Madoc
1,059
Marmora
924
Martintown
P.V.
Maxville
Population
785
Earnings
Domestic service
$ c.
4,856.28
3,484.56
1,016.60
$ c.
3,613.94
1,496.46
131.40
$ c.
807.82
987.08
$ c.
3,191.96
Commercial light service
2,396 57
Commercial power service
Municipal power
Street lighting
1,524.00
1,448.00
300.00
1,430.04
Merchandise
Miscellaneous
69.12
97.87
93.42
30.65
Total earnings
10,950.56
6,787.67
2,188.32
7,049 22
Expenses
Power purchased .
6,878.33
4,194.82
1,085.89
4,888.65
Substation operation
Substation maintenance
Distribution system, operation and
maintenance.
566.96
53.65
29.55
214.57
Line transformer maintenance
Meter maintenance
45.44
Consumers' premises expenses
Street lighting, operation and main-
tenance
193.85
76.50
38.70
59.42
Promotion of business
Billing and collecting
General office, salaries and expenses. .
Undistributed expenses
1,091.32
503.51
130.50
304.13
Truck operation and maintenance. . .
Interest
70.54
447.48
374.00
551.35
720.86
539.00
195 . 19
328.21
135.00
474.86
Sinking fund and principal payments
on debentures. .
872.41
Depreciation
481.00
Other reserves
Total operating costs and fixed
charges
9,667.92
6,639.69
1,943.04
7,295.04
Net surplus
1,282.64
147.98
245 . 28
Net loss
245.82
Number of Consumers
Domestic service
260
98
6
198
44
2
35
22
132
Commercial light service
43
Power service . .
Total
364
244
57
175
934
HYDRO-ELECTRIC POWER COMMISSION
381
"B"— Continued
Hydro Municipalities for Year Ended December 31, 1933
Napanee
3,014
Norwood
727
Omemee
498
Oshawa
23,002
Ottawa
130,672
Perth
3,994
Peterborough
22,809
$ c.
26,679.48
13,744.34
12,225.60
1,467.01
$ c.
4,480.44
2,176.66
626.22
$ c.
2,249.60
1,268.12
1,452.73
$ c.
148,818.93
57,042.47
134,048.33
6,366.23
10,573.28
$ c.
421,647.54
159,028.96
54,871.97
29,594.68
72,933.23
$ c.
22,755 . 27
15,109.94
16,128.17
2,075.60
2,066.00
1,452.85
1,949.87
$ c.
117,648.00
57,718.24
73,455.92
6,386.77
4,473.94
1,578.00
924.00
19,518.00
767.94
400 . 5 1
5,619.03
1,280.86
59,358.31
9,261.83
5,894.45
362,468.27
738,076.38
61,537.70
276,007.79
37,613.44
3,971.85
2,779.53
328,295.17
368,718.84
23,876.25
609.01
23,828.68
2,020.19
10,443.72
3,471.66
25,698.32
10,463 . 05
36,755.94
20,630.80
22,146.16
2,308.87
47,700.61
21,224.29
71,594.00
19,000.00
38,116.49
360.00
196,442.92
5,998.99
356.46
4,264.78
418.45
728.76
375.10
2.50
79.84
5,912.29
367.06
947 . 14
145 . 15
1,677.49
618.48
9,182.16
4,691.14
3,821.12
1,348.51
48.86
597.82
5,543.76
850.54
1,114.00
4,696.52
55.52
267.11
989 . 79
120.00
40.39
522.75
3,067.29
1,599.02
1,440.35
3,100.09
735.21
401.22
2,880.45
1,819.09
3,224.00
6,369.51
3,880.12
2,046.57
479.36
264.06
6,349.90
5,102.62
94.18
189.55
1,743.04
1,026.21
1,027.00
2,423 . 03
1,682.49
2,384.96
1,529.00
235.97
760.29
558.00
12,755.46
11,063.49
9,162.00
964.86
27,488.77
14,263.54
15,627.00
1,200.00
57,672.32
9,285.77
5,095.68
389,603.01
710,490.39
54,594.84
296,047.96
1,685.99
798.77
27,585.99
6,942.86
23.94
27,134.74
20,040.17
770
190
35
217
70
2
126
47
6
5,878
510
98
12,491
1,382
214
934
192
25
5,274
774
155
995
289
179
6,486
14,087
1,151
6,203
382
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Detailed Operating Reports of Electrical Departments of
EASTERN ONTARIO
SYSTEM— Continued
Municipality
Picton
3,217
Port Hope
4,626
Prescott
2,952
Richmond
381
Population
P V
Earnings
Domestic service
$ c.
21,579.51
12,218.11
6,746.07
1,883.78
4,364.04
$ c.
29,372.14
11,563.02
22,168.35
2,101.20
4,615.00
$ c.
15,796.30
8,332.02
3,234.08
1,522.81
3,475.00
$ c.
1,868.77
1,551.59
$ c.
2,535.67
1,284.49
Commercial light service
Commercial power service
Municipal power
Street lighting
500.00
736 00
Merchandise
Miscellaneous
1,588.57
144.58
149.55
5.31
30 08
Total earnings
48,380.08
69,964 . 29
32,509.76
3,925.67
4,586.24
Expenses
Power purchased ....
37,408.54
45,161.39
24,633.82
1,213.64
11.71
2,019.29
88.00
181.45
2,839.73
2,863.50
Substation operation
Substation maintenance
Distribution system, operation and
maintenance
2,076.15
94.37
464 . 19
2,285.05
13.77
1,210.08
1.50
778.79
44.13
54.51
Line transformer maintenance
Meter maintenance
Consumers' premises expenses
Street lighting, operation and main-
tenance
Promotion of business
411.83
7.12
1,167.77
3,255.55
185.32
247.94
54.29
714.66
14.36
112.28
Billing and collecting
1,973.95
4,400.15
958.68
209.76
1,422.16
2,819.40
1,828.00
1,106.59
2,066.11
397.40
General office, salaries and expenses. .
Undistributed expenses
216.10
285.82
Truck operation and maintenance . . .
Interest. . .
343.65
223.05
190.00
419.60
Sinking fund and principal payments
on debentures
2,633.00
417.19
Depreciation
Other reserves
1,832.00
271.00
Total operating costs and fixed,
charges
47,205.07
63,062.68
35,065.67
3,871.02
4,423.90
Net surplus .
1,175 01
6,901 61
54 65
162 34
Net loss .
2,555 91
Number of Consumers
Domestic service
997
204
38
1,238
203
45
655
155
19
53
24
107
Commercial light service
33
Power service
Total
1,239
1,486
829
77
140
1934
HYDRO-ELECTRIC POWER COMMISSION
383
4t B"— Continued
Hydro Municipalities for Year Ended December 31, 1933
Smiths Falls
7,501
Stirling
865
Trenton
6,331
Tweed
1,247
Warkworth
P.V.
Wellington
. 900
Westport
733
$ c.
41,684.74
15,246.98
16,534 14
$ c.
5,346.26
3,351.71
1,812.83
234.45
1,433.00
$ c.
28,302.03
17,524.57
66,346.34
1,897.90
8,076.00
$ c.
6,324.50
4,460.90
2,096.34
204.57
1,886.25
$ c.
2,185.13
1,551.15
$ c.
4,733.77
2,067 . 20
2,128.95
$ c.
3,198.24
2,906.93
225 00
8,342.30
643.75
1,160.04
1,705.00
3,260.40
408.27
2,102.88
10.88
140.80
261.27
122.27
85,293.56
12,586.52
124,249.72
14,983.44
4,520.83
10,351.23
7,932.44
45,792.24
1,921.00
373 29
7,625.67
108.95
85,336.89
9,164.96
3,244.39
7,728.80
4,791.34
15.87
2,346.73
57.07
1,752.11
364.32
1,502.64
16.10
2,632.19
4,651.08
1,455.72
733.61
7,562.22
5,366.67
3,539.00
2,991.14
16.66
1,047.86
867.73
48.35
630.31
251.99
47.26
1,006 02
72.69
75
375.34
69.76
429.46
1,022.46
217.01
367.75
166.22
35
403.30
48.62
562.04
1,000.75
232.50
25.67
93
742.72
20.00
150.52
110.48
3,371.85
4,167.55
1,016.51
175.67
625.87
42.57
418.33
25.50
609 . 48
4,835.95
683.21
647.34
440 . 00
581.61
221.76
199 . 00
828.77
640.02
694 . 00
804 . 55
12,329.72
5,712.00
453.85
953 . 00
207.00
84,886.13
12,290.70
117,332.22
14,217.02
4,490.78
11,366.53
7,111.23
407.43
295.82
6,917.50
766.42
30.05
821.21
1,015.30
1,640
257
44
268
80
10
1,251
220
48
249
92
12
106
43
284
64
6
96
49
1,941
358
1,519
353
149
354
145
384
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT
Detailed Operating Reports of Electrical Departments of
EASTERN ONTARIO
SYSTEM— Concluded
Municipality
Whitby
5,294
Williamsburg
P.V.
Winchester
963
EASTERN
ONTARIO
SYSTEM
SUMMARY
Earnings
Domestic service
$ c.
19,548.69
9,555.38
14,189.33
2,312.74
3,716.43
$ c.
3,702.03
7,503.38
231.98
$ c.
5.870.21
3,363.90
1,548.03
$ c.
1,377,574.45
661,352.71
715,964.74
93,135.34
248,809.48
2,432.01
43,581.42
Commercial light service
Commercial power service
Municipal power
Street lighting
192.00
1,062.00
36.87
363.54
Merchandise.
Miscellaneous
1,355.95
165.44
Total earnings
50,678.52
11,794.83
12,244.55
3 142 850 15
Expenses
Power purchased
37,949.47
5,726.19
8,812.03
1,984,639.39
44,048 88
Substation maintenance
162.12
2,861.02
45.31
456.78
75.77
699 . 47
144.80
1,588.13
1,581.45
251.89
203 . 85
2,175.59
3,475.42
2,837.10
5,421.01
Distribution system, operation and
maintenance
721.37
577.53
106,793.88
Line transformer maintenance
7,512.57
Meter maintenance
36,551.43
Consumers' premises expenses
7,542.11
Street lighting, operation and main-
tenance
60.75
178.95
56,176.49
Promotion of business
13,085.60
Billing and collecting
94,627.71
General office, salaries and expenses. .
Undistributed expenses
378.24
902.46
116,169 12
60,506.02
Truck operation and maintenance . . .
Interest
14,039.53
82.00
200.15
181.00
389.22
384 . 48
598.00
158,412.73
Sinking fund and principal payments
on debentures
130,523.35
Depreciation
176,758.10
Other reserves
47,409.62
Total operating costs and fixed
charges
54,508.17
7,349.70
11,842.67
3,060,217.54
Net surplus. . .
4,445 . 13
401.88
82,632.61
Net loss. . .
3,829.65
Number of Consumers
Domestic service
833
158
21
92
63
1
277
68
2
54,152
Commercial light service
8,707
Power service
1,327
Total
1,012
156
347
64,186
1934
HYDRO-ELECTRIC POWER COMMISSION
385
"B"— Concluded
Hydro Municipalities for Year Ended December 31, 1933
THUNDER BAY
SYSTEM
Fort William
25,188
Nipigon
Port Arthur
19,749
THUNDER
BAY
SYSTEM
SUMMARY
ALL
SYSTEMS
GRAND
SUMMARY
$ c.
200,550.28
61,130.12
43,150.68
23,404.22
17,029.60
$ c.
2,510.41
1,831.65
255.31
724.63
510.00
$ c.
107,395.49
51,764.78
732,490.93
37,667.09
18,984.96
$ c.
310,456.18
114,726.55
775,896.92
61,795.94
36,524.56
$ c.
11,429,101.13
6,013,025.96
9,080,522.07
1,826,872.07
1,779,582.48
12,812.74
7,331.24
18,566.30
25,897.54
485,925.43
352,596.14
5,832.00
966,869.55
1,325,297.69
30,627,841.88
269,607.02
6,169.16
3,115.86
855,196.51
19,665.66
1,066.32
12,045.49
1,570.58
3,866.33
1,127,919.39
25,834.82
1,445.14
22,609.93
1,883.83
10,572.55
293.48
13,214.39
1,822.05
20,913.23
16,657.35
9,181.79
2,846.96
41,106.18
21,454.89
42,481.14
19,857.32
19,330,861.58
484,764.57
378.82
288,583.29
10,090.24
283.77
6,665.82
293.48
474 . 20
29.48
40.40
895,350.99
82,321.32
283,115.98
361,499.20
6,307.37
19.88
6,887.14
1,822.05
9,826.46
10,474.79
4,873.80
1,245.52
17,768.51
8,780.03
30,021.77
18,213.50
353,082.15
259,936 42
11,086.77
817,660.03
5,589.70
4,307.99
592.86
908,517.79
349,101.36
1,601.44
105,452.68
22,960.97
12,241.58
11,986.37
1,643.82
376.70
433 . 28
473.00
2,426,286.35
2,319,319.09
1,894,714.87
94,285.54
371,214.32
5,555.66
1,003,324.46
1,380,094.44
31,254,853.21
276.34
18,618.18
36,454.91
54,796.75
627,011.33
5,260
827
98
134
39
2
4,053
728
97
9,447
1,594
197
452,557
73,628
12,813
6,185
175
4,878
11,238
538,998
1934
HYDRO-ELECTRIC POWER COMMISSION
387
STATEMENT "C"
Street Lighting Installation in Hydro Municipalities, December 31, 1933, showing
Rate per Lamp, Cost to Municipality per Annum, and Cost per Capita.
Municipality
Population
Number
of
lamps
Size and
style of
lamps
Rate per
lamp
per annum
Total cost to
municipality
per annum
Cost
per
capita
Acton
Agincourt
Ailsa Craig. . .
Alexandria. . . .
Alliston
Alvinston ....
Amherstburg. .
Ancaster Twp.
Apple Hill....
Arkona
Arthur
Athens.
Aylmer.
Ayr....
Baden .
Barrie
Bath
Beachville
1,895
464
2,340
1,379
690
3,086
416
1,037
582
1,989
768
7,455
350
127
5
61
1
3
58
61
1
95
41
102
13
84
6
81
9
23
12
32
49
33'
48
92
40
23
168
24
1
92
3
65
464
15
41
23
21
47
80 c.p.
80 c.p.
100 watt
150 watt
300 watt
100 watt
100 watt
200 watt
100 watt
200 watt
100 c.p.
100 watt
100 watt
200 watt
100 c.p.
250 c.p.
200 watt
300 watt
100 watt
150 watt
100 watt
100 watt
100 watt
100 watt
200 watt
100 watt
300 watt
Traffic Light
100 watt
500 watt
100 watt
100 c.p.
100 watt
200 watt
300 watt
100 watt
1,00 watt
$ c
9.00)
12.00
9.00
12.00
20. 00,
13.00
10.00
18.00
17.00)
25.00/
18.00)
18.00/
20.00\
29.00/
15.00]
30.00
20 . 00 (
30.00J
12.50)
15.00/
17.00
20.00
19.00
14.00)
30.00/
10.00)
25.00[
40.00J
10.00/
36.00/
10.00
9.00)
17.00
22.00
25. 00 J
34.00
11.00
$ c.
1,824.00
750.04
620.50
2,640.00
2,070.00
1,854.00
2,270.22
1,135.00
559.75
960.00
1,748.00
1,250.00
2,320.00
1,028.00
650.00
5,961.25
714.00
517.00
**Population not shown in Government statistics. 5 Series system. m Multiple system.
tfPart cost paid direct in the form of debenture charges.
388
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT "C"— Continued
Street Lighting Installation in Hydro Municipalities, December 31, 1933, showing
Rate per Lamp, Cost to Municipality per Annum, and Cost per Capita.
Municipality
Population
N
umber
of
amps
Size and
style of
lamps
Rate per
lamp
per annum
Total cost to
municipality
per annum
Cost
per
capita
Beaverton
960
1
9
104
100 watt
100 watt
500 watt
m
m
m
$ c.
7.001
10.00
30.00J
$ c.
1,286.52
$ c.
1.34
Beeton
584
{
65
14
150 c.p.
100 watt
s
m
15.00\
15.00/
1,185.00
2.03
Belle River
746
63
100 watt
m
11.00
693.00
.93
Belleville
14,059
1
1
542
22
52
103
100 c.p.
400 c.p.
1,000 c.p.
300 watt
s
s
s
m
9.001
28.001
52.00
33. OOj
11,655.86
.83
Blenheim
1,690
J
1
163
12
150 c.p.
400 c.p.
600 c.p.
Traffic Light
s
s
5
HI
12.001
28.00
37.00
16. OOJ
2,500.00
tt
Bloomfield
614
60
80 c.p.
s
12.00
720.00
1.17
Blvth
602
100
100 watt
111
13.00
1,300.00
2.16
Bolton
593
f 45
I 23
100 watt
200 watt
m
m
13.00\
23.00/
1,113.99
1.88
Bothwell
646
J
1
66
21
100 watt
300 watt
m
m
11.00\
27.00/
1,293.00
2.00
Bowman ville. . .
3,641
171
4
42
80 c.p.
150 watt
300 watt
s
m
m
14.001
27.00
37.00J
4,057.17
1.11
Bradford
1,009
\
' 60
80 c.p.
100 watt
s
m
19.001
19.00/
1,273.00
1.26
Brampton
5,413
f 659
100 watt
500 watt
Fire Alarm
m
m
8.001
35.00l
6.50j
5,426.50
1.00
Brantford
30,724
*
[ 149
3,501
10
12
2
2
20
1,500 c.p.
100 watt
150 watt
200 watt
300 watt
500 watt
750 watt
s
m
m
m
m
m
m
45.00
7.50
8.50
11.00
16.00
45.00
46.00
•
34,414.16
tt
Brantford Twp.
369
32
100 watt
100 watt
m
m
11.00
18.00
4,250.50
576.00
**
Brechin
X
**
Bridgeport
58
100 watt
m
10.00
580.00
**
**Population not shown in Government statistics. s Series system.
ttPart cost paid direct in the form of debenture charges.
m Multiple system.
^Includes Mara and Thorah Townships.
1934
HYDRO-ELECTRIC POWER COMMISSION
389
STATEMENT "C"— Continued
Street Lighting Installation in Hydro Municipalities, December 31, 1933, showing
Rate per Lamp, Cost to Municipality per Annum, and Cost per Capita.
Municipality
Population
Number
of
lamps
Size and
style of
lamps
Rate per
lamp
per annum
Total cost to
municipality
per annum
Cost
per
capita
Brigden
r 4i
I 21
60 watt
100 watt
m
m
$ c.
11.001
14.00/
$ c.
745.00
$ c.
**
Brighton
1,413
137
80 c.p.
s
12.00
1,644.00
1.16
Brockville
9,615
■
' 589
15
35
49
6
100 c.p.
1-Lt. stds.
3-Lt. stds.
5-Lt. stds.
300 watt
s
m
m
m
m
11.00
17.00
21.00
24.00
24.00
'
8,772.50
.91
Brussells
770
/ 80
I 18
100 watt
200 watt
m
m
12.001
18.00/
1,284.00
1.67
Burford
67
24
100 watt
100 watt
m
m
11.00
13.0
737.04
312.00
**
Burgessville. . . .
**
Caledonia
1,400
f 158
20
I 8
100 watt
100 watt
100 watt
m
m
m
8.001
9.50}
13.00J
1,546.98
1.10
Campbellville. .
19
100 watt
m
24.00
456.00
**
Cannington. . . .
851
11
100 watt
300 watt
500 watt
m
m
m
14.00]
22.00
32.00J
1,022.00
1.20
Cardinal
1,305
/ 16
I 41
100 watt
- 200 watt
m
m
15.001
21.00/
1,066.00
.81
Carleton Place .
4,272
{ 84
\ 102
1 67
60 watt
200 watt
300 watt
m
m
m
12.00]
18.00}
23.00J
4,385.00
1.03
Cayuga
705
85
100 watt
m
18.00
1,431.00
2.03
Chatham
16,223
f 35
715
32
75
33
136
I 2
150 c.p.
150 c.p.
250 c.p.
600 c.p.
600 c.p.
1,000 c.p.
250 watt
s
s
s
s
s
s
m
12 00]
13.00
16.00
30.00
31.00
38.00
24. 00,
19,009.95
tt
Chatsworth. . . .
272
41
100 watt
m
12.00
492.00
1.81
Chesley
1,789
114
150 c.p.
s
14.00
1,596.00
.89
Chesterville. . . .
950
86
100 watt
m
12.00
1,032.00
1.09
Chippawa
1,073
93
100 watt
m
12.00
1,096.00
1.02
Clifford
454
62
100 watt
m
14.00
862.17
1.90
Clinton
1,842
( 149
22
I 1
150 c.p.
100 watt
500 watt
s
m
m
11.00]
11.00
55.00J
1,987.02
1.08
**Population not shown in Government statistics. 5 Series system.
tfPart cost paid direct in the form of debenture charges.
m Multiple system.
390
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT "C"— Continued
Street Lighting Installation in Hydro Municipalities, December 31, 1933, showing
Rate per Lamp, Cost to Municipality per Annum, and Cost per Capita.
Municipality
Population
Number
of
lamps
Size and
style of
lamps
Rate per
lamp
per annum
Total cost to
municipality
per annum
Cost
per
capita
Cobourg
5,619
(
387
4
18
100 c.p.
250 c.p.
500 watt
5
m
$ c.
12.001
23.00
47.50J
$ c.
5,584.04
$ c.
.99
Colborne
977
117
80 c.p.
s
12.00
1,287.00
XX
Coldwater
626
J
1
6
47
60 watt
100 watt
m
m
9.00\
11.00/
571.00
.91
Collingwood . . .
5,788
422
100 c.p.
s
8.00
3,013.33
.52
Comber
26
56
100 watt
150 c.p.
m
18.00
18.00
512.00
1,008.00
**
Cookstown ....
**
Cottam
31
43
100 watt
100 watt
m
m
15.00
18.00
457.50
774.00
**
Courtright
348
2.22
Creemore
587
59
100 watt
m
12.00
673.63
1.15
Dash wood
41
22
128
100 watt
100 watt
100 c.p.
m
m
s
11.00
12.00
14.00
451.00
264.00
1,791.96
**
Delaware
**
Deseronto
1,418
\.2t
Dorchester ....
59
75
100 watt
100 watt
m
m
10.00
10.00
590.00
750.00
**
Drayton
559
1.3-1
Dresden
1,488
{
130
15
100 c.p.
50 watt
s
m
13.00\
4.56/
1,758.36
1.12
Drumbo
{
39
1
100 watt
250 watt
m
m
13.001
31.00/
522.50
**
Dublin
50
82
100 watt
100 watt
m
m
15.00
14.00
750.00
1,220.00
**
Dundalk
647
1.8S
Dundas
5,138
1
285
16
27
100 watt
200 watt
300 watt
m
m
m
12.001
16.00}
37.00J
5,388.00
1.0=
Dunnville
3,615
{
247
27
150 c.p.
1,000 c.p.
s
s
11.001
45.00/
3,941.88
1.09
Durham
1,800
{
105
6
150 c.p.
400 c.p.
s
s
17.001
25.00/
1,935.00
l.«
Dutton
761
111
100 watt
m
9.00
999.37
1.31
East Windsor. .
14,333
{
338
194
100 watt
200 watt
m
m
8.00
14.00
\
8,419.92
tt
**Population not shown in Government statistics. s
fjPart cost paid direct in the form of debenture charge
jjll months' operation.
Series system. m Multiple system.
934
HYDRO-ELECTRIC POWER COMMISSION
39
STATEMENT "C"— Continued
Street Lighting Installation in Hydro Municipalities, December 31, 1933, showing
Rate per Lamp, Cost to Municipality per Annum, and Cost per Capita.
Municipality
Population
Number
of
lamps
Size and
style of
lamps
Rate per
lamp
per annum
Total cost to
municipality
per annum
East York Twp
Elmira.
Elmvale. .
Elm wood.
Elora . . . .
Embro
Erieau .
Essex . .
Etobicoke Twp
Exeter
Fergus ,
Finch . .
Flesherton
Fonthill. . .
Forest
Fort William.
2,642
,144
455
264
1,622
2,559
383
491
862
1,465
25,188
1
942
4
268
15
190
8
1
50
23
81
27
56
20
121
29
4
61
1
965
22
167
23
140
37
38
2
53
1
71
131
123
572
2
13
73
266
60 watt
100 watt
200 watt
300 watt
50 watt
100 watt
200 watt
500 watt
100 watt
150 watt
100 watt
200 watt
100 watt
100 watt
60 watt
100 watt
200 watt
300 watt
500 watt
100 watt
100 watt
100 watt
200 watt
100 watt
150 watt
100 watt
60 watt
100 watt
300 watt
100 watt
60 watt m
100 watt m
Station Platform
100 c.p.
250 c.p.
300 c.p.
600 c.p.
1,000 c.p.
* c.
7.80]
13.00
19.50
26.00
29.00
9.001
12.00
28. 00 J
13.00
23.00
14.00
20.00
12.00
18.00
11.00
11.00
22.00
24.00
30.00
13.50
18.00
9.50
18.00
14.00
16.50
15.00
6.00
11.00
26.00
15.00
7.00
11.00
51.00
8.00
18.00
23.00
28.00
38.00
$ c.
19,637.45
1,834.00
662.31
529.00
1,674.00
672.00
360.00
3,134.99 1.66
13,415.13
1,998.94
2,915.04
502.50
621.00
1,065.00
2,321.00
17,029.60
'Population not shown in Government statistics. s Series system.
Multiple system.
392
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT "C"— Continued
Street Lighting Installation in Hydro Municipalities, December 31, 1933, showing
Rate per Lamp, Cost to Municipality per Annum, and Cost per Capita.
Number
Size and
Rate per
Total cost to
Cost
Municipality
Population
of
style of
lamp
municipality
per
lamps
lamps
per annum
per annum
capita
$ c.
$ c.
$ c.
f 972
100 c.p. 5
9.00
158
100 watt m
12.00
Gait
14,036
,
51
200 watt m
20.00
.
21,384.00
1.52
146
300 watt m
35.00
1 6
500 watt m
26. 00,
f 174
100 watt m
11.001
Georgetown. . . .
2,187
1 l ?
100. watt m
300 watt m
13.00
19.00J
2,125.83
*
Glencoe
800
f 325
100 watt m
200 watt m
100 c.p. s
14.00\
20.00/
9.001
1,934.00
2.42
Goderich
4,366
8
I 16
100 watt m
200 watt m
3-Lt. stds. m
15.00
25.00
35.00J
3,791.50
.87
Grand Valley . .
587
52
100 watt m
18.00
936.00
1.59
Granton
37
f 135
100 watt m
80 c.p. 5
10.00
370.00
**
10.00
Gravenhurst . . .
1,830
7
30
100 c.p. 5
100 watt m
11.00
10.00
2,096.24
1.15
I 16
300 watt m
35.00J
' 12
50 watt m
4.001
6
60 watt m
4.00
1,351
100 watt m
10.00
Guelph
20,754
<
173
34
9
53
1
200 watt m
300 watt m
500 watt m
500 watt, 220v m
Airport Beacon m
12.50
18.75
25.00
34.00
60.00
>
18,499.79
.89
Hagersville ....
1,370
/ 116
I 17
100 watt m
300 watt m
12.001
20.00/
1,732.00
1.26
10
40 watt m
4.501
96
50 watt m
6.00
8,270
100 watt m
7.50
7
100 watt m
12.00
1,166
200 watt m
11.00
8
300 watt m
18.00
Hamilton
154,701
28
94
5
480
596
65
3
2
300 watt m
300 watt m
300 watt m
500 watt m
500 watt m
750 watt m
Danger Sig. Stds.
Danger Sig. Stds.
26.00
32.00
34.00
32.00
37.00
55.00
28.00
70.00
123,449.34
.80
**Population not shown in Government statistics. 5 Series system.
tfPart cost paid direct in the form of debenture charges,
includes Glen Williams.
m Multiple system.
1934
HYDRO-ELECTRIC POWER COMMISSION
393
STATEMENT "C"— Continued
Street Lighting Installation in Hydro Municipalities, December 31, 1933, showing
Rate per Lamp, Cost to Municipality per Annum, and Cost per Capita.
Municipality
Population
Number
of
lamps
Size and
style of
lamps
Rate per
lamp
per annum
Total cost to
municipality
per annum
Cost
per
capita
Hanover
3,036
( s
100 c.p.
200 c.p.
100 watt
200 watt
5
5
m
m
$ c.
27.001
32.00
27.00
32.00,
$ c.
3,488.16
$ c.
1.15
Harriston
1,293
f 82
4
29
150 c.p.
100 watt
200 watt
s
m
m
12.001
12.00
15.00J
1,467.00
1.13
Harrow
926
I 75
100 watt
200 watt
m
m
12.00\
16.50/
1,249.44
1.35
Hastings
707
(1
100 watt
100 watt
100 watt
m
m
m
24.001
30.00
39.00J
1,550* 92
2.19
Havelock
1,096
<
f 63
I 20
100 c.p.
250 c.p.
s
s
16.00)
25.00/
1,508.00
1.38
Hensall
719
S3
100 watt
m
12.00
996.00
1.39
Hespeler
2,784
' 91
34
15
51
10
7
150 c.p.
250 c.p.
400 c.p.
150 watt
300 watt
300 watt
s
s
s
m
m
m
11.00
16.00
30.00
10.00
21.50
35.00,
-
2,965.00
1.07
Highgate
338
<
r 45 -
t 6
100 watt
200 watt
m
m
11.00)
17.00/
568.00
1.68
Holstein
14
100 watt
m.
35.00
490.00
**
Humberstone . .
2,265
<
' 104
100 watt
200 watt
m
m
12.00)
17.00/
1,367.00
.60
Huntsville
2,507
<
f 47
25
28
68
118
100 c.p.
150 c.p.
250 c.p.
75 watt
60-75 watt
Per 1,000
s
s
s
m
m
w.
14.00 N
18.00
22.00
10.00
42.00J
2,675.00
1.07
Ingersoll
5,296
.
' 13
310
2
2
26
11
100 c.p.
100 c.p.
600 c.p.
1,000 c.p.
1,000 c.p.
300 watt
5
S
S
S
s
m
5.50
11.00
28.00
25.00
35.00
30.00,
>
4,851.48
ft
Jarvis
504
70
100 watt
m
12.00
840.00
1.67
**Population not shown in Government statistics. 5 Series system.
tfPart cost paid direct in the form of debenture charges.
m Multiple system.
394
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT "C"— Continued
Street Lighting Installation in Hydro Municipalities, December 31, 1933, showing
Rate per Lamp, Cost to Municipality per Annum, and Cost per Capita.
Municipality
Population
Number
of
lamps
Size and
style of
lamps
Rate per
lamp
per annum
Total cost to
municipality
per annum
Kemptville
Kincardine.
Kingston . .
Kingsville.
Kirkfield.
Kitchener
Lakefield .
Lambeth .
Lanark. . .
Lancaster
La Salle. .
Leamington
Lindsay. . . .
Listovvel
1,227
2,429
23,260
2,286
31,443
1,303
636
601
600
5,025
7,109
2,665
90
1
151
56
1
93
289
243
113
25
122
23
47
2,031
90
18
200
436
40
109
108
36
1
37
41
66
21
100
4
192
/ 414
\ 25
162
118
8
26
3
100 watt m
250 w. Fl. light m
150 c.p.
100 watt
1 ,000 watt
100 c.p.
600 c.p.
600 c.p.
150 c.p.
250 c.p.
100 watt
100 watt
16 c.p.
80 c.p.
250 c.p.
1,000 c.p.
100 watt
200 watt
300 watt
500 watt
100 watt
100 watt
300 watt
100 watt
100 watt
100 watt
250 c.p.
400 c.p.
600 c.p.
100 watt
100 c.p.
1,000 c.p.
60 watt
100 watt
200 watt
300 watt
500 watt
$ c.
20.00
30.00
20.00
15.00
85.00
15.00
40.00
52.00
12.001
16.00>
12.00J
20.00
7.00)
9.00
13.00
25.00
9.00
15.00
17.50
25.00,
17.00
12.00V
27.00/
16.00
36.50
15.00
16.00)
20.001
26.00
15.00J
15.00\
70.00/
9.00
11.00
25.00
30.00
35.00
$ c.
1,830.00
4,022.50
25,486.08
3,220.00
460 . 00
32,415.74
1,836.00
459.00
592.00
1,496.50
577.50
5,456.34
8,172.90
3,839.10
**Population not shown in Government statistics. 5 Series system.
tJPart cost paid direct in the form of debenture charges.
m Multiple system.
1934
HYDRO-ELECTRIC POWER COMMISSION
395
STATEMENT "C"— Continued
Street Lighting Installation in Hydro Municipalities, December 31, 1933, showing
Rate per Lamp, Cost to Municipality per Annum, and Cost per Capita.
Municipality
Population
Number
of
lamps
Size and
style of
lamps
Rate per
lamp
per annum
Total cost to
municipality
per annum
London
London Twp.
73,173
Long Branch. . .
3,541
Lucan
590
1,082
Lucknow
Lynden
Madoc
1,059
Markdale
774
Markham
1,073
Marmora
924
Martintown . . .
Maxville
785
Meaford
2,707
Merlin
Merritton
2,544
Midland
6,808
8
1,920
103
301
32
273
2
75
12
47
43
488
36
11
68
68
1
36
232
71
73
43
342
7
1
90
113
44
24
19
15
65
180
28
35
43
/ 303
1 25
326
52
30
36
150 c.p.
150 c.p.
400 c.p.
400 c.p.
600 c.p.
600 c.p.
50 watt
100 watt
200 watt
200 watt
200 watt
300 watt
300 watt
500 watt
500 watt
100 watt
200 watt
100 watt
100 watt
100 watt
100 watt
100 watt
75 watt
150 watt
300 watt
150 c.p.
100 watt
75 watt
100 watt
150 watt
100 watt
100 c.p.
150 c.p.
100 watt
200 watt
100 watt
100 watt
300 watt
100 c.p.
100 watt
300 watt
500 watt
$ c.
10.00
24.00
28.00
30.00
2.50
10.00
9.34
14.00
18.00
18.00
20.00
25.00
40.00,
12.001
16.50/
950\
13.00/
14.00
21.00
10.00
5.00)
6.00
12.00J
10.00
12.00
15.00]
17.00}-
20.00J
20.00
22.00
12.00
12.00
20.00
16.00
9.00\
25.00/
10.00
10.00
22.00
40.00
$ c.
54,028.74
832.50
3,413.27
992 . 70
1,522.50
431.80
1,524.00
900.00
1,356.00
1,448.00
300.00
1,430.04
3,219.19
688.00
3,352.00
6,175.84
**Population not shown in Government statistics. 5 Series system. m Multiple system.
tfPart cost paid direct in the form of debenture charges.
396
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT "C"— Continued
Street Lighting Installation in Hydro Municipalities, December 31, 1933, showing
Rate per Lamp, Cost to Municipality per Annum, and Cost per Capita.
Municipality
Population
IN
umber
of
amps
Size and
style of
lamps
Rate per
lamp
per annum
Total cost to
municipality
per annum
Cost
per
capita
Mildmay
694
1
1
42
11
100 watt
150 watt
m
m
$ c.
15.00\
21.50/
$ c.
659.56
$ c
.95
Milton
1,828
J
1
' 204
3
100 watt
300 watt
m
m
9.50\
30.00/
2,019.50
1.10
Milverton
1,004
J
1
95
12
100 watt
200 watt
m
m
9.00\
12.00/
999 . 00
l.OC
Mimico
6,454
1
330
91
47
100 watt
200 watt
300 watt
m
m
m
14.00 |
21.50[
28.00J
8,021.89
1.24
Mitchell
1,571
232
150 c.p.
s
9.00
2,088.00
1.33
Moorefield
25
50
100 watt
100 watt
m
m
15.00
10.00
375.00
500.00
**
Mount Brydges.
**
Mount Forest . .
1,821
f 117
14
35
150 c.p.
250 c.p.
100 watt
s
s
m
12.00]
14.00
12.00J
2,370.00
1.3C
Napanee
3,014
f 142
26
40
I 1
80 c.p.
250 c.p.
300 watt
1,000 watt
s
s
m
m
16.00)
37.001
32. 00[
63.00J
4,473.94
1.4*
Neustadt
465
39
150 c.p.
s
25.00
975.00
2.1C
Newbury
267
48
100 watt
m
15.00
720.00
2.7C
New Hamburg.
1,426
/ 163
I 61
100 watt
200 watt
m
m
9.00\
12.00/
2,258.75
1.5*
New Toronto . .
7,280
' 221
17
15
28
14
131
3
75 watt
150 watt
200 watt
300 watt
300 watt
500 watt
Intersection 1
m
m
m
m
m
m
ights
15.00
18.00
19.00
22.00
27.00
30.00
28.00 /
•
8,913.96
1.22
Niagara Falls. .
18,507
■
805
2
234
197
4
100 c.p.
250 c.p.
600 c.p.
1,000 c.p.
100 watt
5
S
S
m
11.00
13.00
40.00
45.00
11.00,
28,392.66
1.53
Niagara-on-the
Lake
1,672
1
r 219
, 25
100 watt
200 watt
m
m
11.00)
18.00/
2,833.31
i.6t
Nipigon
34
100 watt
m
15.00
510.00
**
Population not shown in Government statistics. s Series system. m Multiple system.
1934
HYDRO-ELECTRIC POWER COMMISSION
397
STATEMENT "C"— Continued
Street Lighting Installation in Hydro Municipalities, December 31, 1933, showing
Rate per Lamp, Cost to Municipality per Annum, and Cost per Capita.
Municipality
Population
Number
of
lamps
Size and
style of
lamps
Rate per
lamp
per annum
Total cost to
municipality
per annum
Cost
per
capita
North York
Twp
Norwich . . .
Norwood . .
Oil Springs
Omemee. . .
Orangeville
Oshawa . . .
Ottawa
Otterville.
Owen Sound
Paisley
1,126
727
433
498
2,785
23,002
130,672
12,803
732
81
20
32
12
10
65
1
2
1
1
1
114
28
78
6
1
40
1
46
2
10
48
99
38
834
1
40
109
30
618
389
789
813
59
2,940
54
12
433
339
12
39
88
100 watt
100 watt
100 watt
100 watt
100 watt
200 watt
400 w. Fl. light m
1,000 w. Fl light m
Safety Lamp
Safety Lamp
Police Sign
100 watt
400 watt
100 c.p.
100 c.p.
100 c.p.
100 watt
300 watt
80 c.p.
100 watt
250 watt
250 c.p.
150 c.p.
300 watt
100 c.p.
1,000 c.p.
100 watt
150 watt
200 watt
100 c.p.
100 c.p.
400 c.p.
600 c.p.
Arc Lights
100 watt
100 watt
200 watt
100 c.p.
250 c.p.
400 c.p.
500 c.p.
100 watt
48c.
$ c.
12.00
13.00
13.50
15.00
16 50
23.00
31.00
65.00
8.00
30.00
12.00
10.00
35.00
18.00
20.00
27.00
18.00
60.00
14.00
12.50
28.00
20 00
15.00
35.00
10.00
27.00
11.00
12.00
16.00
6
001
7
00
25
00
35
OOf
45
00
per
ft.j
11.00
16.00
11.00 N
14 00
21.00
35. 00^
16.00
3,675.61
2,120.00
1,578.00
750.00
924.00
3,760.20
10,573.28
72,933.23
780.51
11,181.23
1,408.00
$ c.
1.97
2.17
1.73
1.86
1.35
.46
.56
87
1.92
Population not shown in Government statistics. s Series system. m Multiple system.
398
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT "C"— Continued
Street Lighting Installation in Hydro Municipalities, December 31, 1933, showing
Rate per Lamp, Cost to Municipality per Annum, and Cost per Capita.
Municipality
Population
Number
of
lamps
Size and
style of
lamps
Rate per
lamp
per annum
Total cost to
municipality
per annum
Cost
per
capita
Palmerston ....
1,617
'
95
7
4
1
10
2
14
2
15
1
80 c.p.
100 c.p.
250 c.p.
40 watt
60 watt
100 watt
150 watt
250 watt
300 watt
500 watt
5
5
m
m
m
m
m
m
m
% c.
9.001
10.00
25.00
9.00
9.00
10.00
10.00
25.00
25.00
35.00
■
$ c.
1,738.98
$ c.
1.08
Paris
4,330
■
' 466
10
25
2
2
6
2
100 c.p.
400 c.p.
500 c.p.
60 watt
100 watt
500 watt
500 watt
s
s
s
m
m
m
m
9.00^
32.00
40.00
7.00
9.00
35.00
40.00,
5,838.90
1.35
Parkhill
998
f 78
I 15
100 watt
200 watt
m
m
14.00\
23.00/
1,437.00
1.44
Penetanguishene
4,046
' 184
3
I 4
100 watt
200 watt
300 watt
m
m
m
11.00]
15.00}
20.00]
2,149.00
.53
Perth
3,994
f 70
J 12
1 A
100 c.p.
250 c.p.
400 c.p.
600 c.p.
s
s
s
s
15.00)
25.001
28.00
40. 00 J
2,066.00
.52
Peterborough . .
22,809
f 115
215
362
501
400 c.p.
60 watt
100 watt
300 watt
s
m
m
m
43.00]
9.00
10.00
18.00J
-19,518.00
.8c
Petrolia
2,569
/ 145
I 24
150 c.p.
600 c.p.
s
s
12.00\
38.00/
2,652.00
1.03
Picton
3,217
/ 222
\ 85
100 c.p.
250 c.p.
s
s
12.00\
20.00/
4,364.04
1.3(
Plattsville
34
r 99
\ 15
100 watt
150 c.p.
250 c.p.
m
s
s
13.00
13.00\
20.00/
442.00
1,553.66
**
Point Edward . .
1,211
1.21
Port Arthur
19,749
f 2,709
\ 232
[ 208
100 watt
300 watt
500 watt
m
m
m
5.001
10.00V
15.00J
18,984.96
.9(
Port Colborne. .
6,006
r 15
78
127
34
232
400 c.p.
600 c.p.
100 watt
100 watt
200 watt
5
S
m
m
m
23.00
25.00
12.00
14.00
18.00
►
7,825.80
tt
**Population not shown in Government statistics. 5 Series system.
tfPart cost paid direct in the form of debenture charges.
m Multiple system.
1934
HYDRO-ELECTRIC POWER COMMISSION
399
STATEMENT "C"— Continued
Street Lighting Installation in Hydro Municipalities, December 31, 1933, showing
Rate per Lamp, Cost to Municipality per Annum, and Cost per Capita.
Municipality
Population
Number
of
lamps
Size and
style of
lamps
Rate per
lamp
per annum
Total cost to
municipality
per annum
Port Credit
1,650
271
100 watt
m
% c.
10.00
$ c.
2,710.00
$ c.
1.64
Port Dalhousie.
1,331
<
f 128
I 2
100 watt
200 watt
m
m
12.50\
15.00/
1,630.00
1.22
Port Dover ....
1,680
<
r 178
I 19
100 watt
300 watt
m
m
12.00\
20.00/
2,964.17
1.76
Port Elgin
1,230
<
r in
l 26
100 watt
200 watt
m
m
14.00)
22.00/
2,103.79
1.71
Port Hope
4,626
385
80 c.p.
s
12.00
4,615.00
1.00
Port McNicoll..
928
<
f 47
I 17
100 watt
200 watt
m
m
12.50\
20.00/
927.50
1.00
Port Perry
1,130
100
100 watt
m
15.00
1,500.00
Port Rowan . . .
674
53
100 watt
m
24.00
1,242.00
1.84
Port Stanley. . .
723
182
100 watt
m
11.00
2,003.16
2.77
Prescott
2,952
/ 169
\ 105
100 watt
100 w. 2-Lt.Std
m
. m
io.oo\
17.00/
3,475.00
1.18
Preston
6,138
1
f 345
9
40
L 6
150 c.p.
250 watt
500 watt
5-Lt. Stds.
s
m
m
10.00]
18.001
30.00
30.00J
4,986.96
.81
Priceville
14
100 watt
m
40.00
560.00
**
Princeton
37
100 watt
m
13.00
481.00
**
Queenston
36
100 watt
m
16 00
456 10
**
Richmond
381
25
100 watt
m
20.00
500.00
1.31
Richmond Hill.
1,270
1
' 99
17
[ 6
75 watt
100 watt
200 watt
m
m
m
11.00]
12.00[
16.00J
1,389.00
1.09
Ridgetown
1,942
•
' 186
1
73
2
. 19
150 c.p.
1,000 c.p.
100 watt
200 watt
500 watt
s
s
m
m
m
9.00]
40.00
9.00
30.00
36.00 ;
3,115.00
tt
Ripley
451
\
r 43
, 6
100 watt
200 watt
m
m
24.00\
39.00/
1,266.00
2.81
Riverside
5,125
\
' 95
k 24
100 watt
150 watt
m
m
11.00)
14.50/
2,919.72
tt
Rockwood
85
100 watt
m
9 00
765.00
**
**Population not shown in Government statistics. s Series system. m Multiple system.
ttPart cost paid direct in the form of debenture charges.
400
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT "C"— Continued
Street Lighting Installation in Hydro Municipalities, December 31, 1933, showing
Rate per Lamp, Cost to Municipality per Annum, and Cost per Capita.
Municipality
Population
Number
of
lamps
Size and
style of
lamps
Rate per
lamp
per annum
Total cost to
municipality
per annum
Rodney .
Rosseau
Russell. .
St. Catharines.
St. George.
St. Jacobs.
St. Marys.
St. Thomas.
* Sandwich.
Sarnia
Scarboro Twp.
Seaforth
757
251
26.192
4,016
16,275
11,017
17,801
1,692
78
14
35
46
2,695
39
46
224
105
20
32
1,065
28
1
114
6
22
272
303
71
31
10
33
f 1,024
56
65
79
13
3
8
14
10
216
2
19
2
25
409
7
10
154
153
65
58
20
100 watt m
200 watt m
100 watt m
100 watt
100 watt
100 watt
100 watt
100 c.p.
250 c.p.
150 watt
300 watt
100 c.p.
250 c.p.
600 c.p.
600 c.p.
60 watt
300 watt
100 c.p.
100 c.p.
400 c.p.
400 c.p.
100 watt
200 watt
150 c.p.
250 c.p.
400 c.p.
600 c.p.
600 c.p.
100 watt
150 watt
300 watt
80 c.p.
80 c.p.
150 c.p.
40 watt
60 watt
100 watt
100 watt
200 watt
200 watt
300 watt
300 watt
80 c.p.
100 c.p.
300 watt
% c.
10.00
18.00
35.42
16.00
7.50
9.50
10.00
9.001
14.00 1
9.00
14.00J
9.001
13.00
32.00
34. OOf
4.50
22.00
12
00)
13
00
26
.00
28.00
12
.00
21
.00 J
12
001
16
50
22
00
35
00
45
oof
12
00
16
50
32
00 J
9
00 N
12
00
17
00
12
00
18
00
9
00
12
00
17
00
21
00
14
50
24
00 j
10.00
11.00
25.00
$ c.
1,032.02
1,240.00
736.00
20,524.24
370.50
460 . 00
4,096.75
14,604.46
9,874.46
18,456.98
14,911.65
1,788.00 1.06
**Population not shown in Government statistics. 5 Series system.
ttPart cost paid direct in the form of debenture charges.
*11 months' operation.
m Multiple system.
1934
HYDRO-ELECTRIC POWER COMMISSION
401
STATEMENT "C"— Continued
Street Lighting Installation in Hydro Municipalities, December 31, 1933, showing
Rate per Lamp, Cost to Municipality per Annum, and Cost per Capita.
Number
Size and
Rate per
Total cost to
Cost
Municipality
Population
of
style of
lamp
municipality
per
lamps
lamps
per annum
per annum
capita
$ c.
$ c.
$ c.
Shelburne
1,064
96
100 watt
m
10.00
960 . 00
.90
f 272
100 c.p.
s
11.00
27
1,000 c.p.
s
40.00
7
150 watt
m
11.00
Simcoe
5,397
8
6
2
I 1
200 watt
200 watt
500 watt
1,000 watt
m
m
m
m
15.00
24.00
53.00
60. 00,
4,527.48
tt
f 18
60 watt
m
9.50)
Smiths Falls. . .
7,501
<
105
254
100 watt
200 watt
m
m
18.001
25.00
8,342.30
1.11
300 watt
hi
25.00J
39
60 watt, Beach
\
Lamps
m
12.00
Southampton . .
1,520
"
104
30
100 watt
250 watt
m
m
13.00
21.00
2,106.92
1.39
Decorative Lights
36.00.
Springfield
379
50
100 watt
m
11.00
550.00
1.45
Stamford Twp. .
848
100 watt
m
9.50
7,914.64
**
Stayner
1,042
<
r 75
I 18
150 c.p.
200 watt
s
m
12.001
18.00/
1,224.00
1.17
Stirling
865
120
100 c.p.
s
12.00
1,433.00
1.66
Stouffville
1,105
124
100 watt
m
14.00
1,764.00
1.60
' 861
100 c.p.
s
10.00^
74
600 c.p.
s
25.00
116
600 c.p.
s
30.00
Stratford
18,869
6
62
4
4
600 c.p.
1,030 c.p.
100 watt
500 watt
s
s
m
m
35.00
34.00
10.00
34.00J
16,539.00
.88
' 298
100 c.p.
s
9.001
Strathroy
2,879
1
21
k 34
250 c.p.
300 watt
s
m
15.00
31. 00 J
4,075.71
1.42
Sunderland ....
{
' 29
100 watt
500 watt
m
m
20.00)
35.00/
706.67
**
117
100 watt
in
13.00)
Sutton
809
15
16
200 watt
100 w. strings
m
m
1 7 . 00
13.00J
1,861.00
2.30
Tara
491
70
100 watt
m
18.00
1,260.00
2.57
Tavistock
1,042
J
1
78
36
100 watt
200 watt
m
m
10.00)
12.00]
1,212.00
1.16
**Population not shown in Government statistics. 5 Series system.
tfPart cost paid direct in the form of debenture charges.
m Multiple system.
402
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT "C"— Continued
Street Lighting Installation in Hydro Municipalities, December 31, 1933, showing
Rate per Lamp, Cost to Municipality per Annum, and Cost per Capita.
Municipality
Population
Number
of
lamps
Size and
style of
lamps
Rate per
lamp
per annum
Total cost to
municipality
per annum
Cost
per
capita
Tecumseh
2,546
i 8
\ 60
400 c.p. 5
100 watt m
$ c.
21.00\
12.00/
$ c.
960.00
$ c.
tt
Teeswater
805
/ 38
\ 20
150 c.p. 5
400 c.p. 5
19.001
34.00/
1,402.00
1.74
47
100 watt m
11.00
517 00
**
Thamesville. . . .
754
( 67
\ 33
{ 7
100 watt m
200 watt m
200 watt m
9.00)
14.00^
18.00J
1,191.00
1.57
Thedford
577
69
100 watt m
15.00
1,035.00
1.79
Thorndale
32
100 watt m
12.00
384.00
**
22
f 382
J 40
1 1
100 watt m
75 watt m
100 watt m
200 watt m
300 watt m
40.00
7.50)
8.001
12.00
15.00J
880 . 00
3,551.00
**
Thorold
5,068
.70
Tilbury
1,996
/ 100
I 25
100 watt m
200 watt m
11.001
19.50/
1,580.22
.79
Tillsonsburg. . .
3,351
[ 264
1
{ 44
100 c.p. 5
250 c.p. 5
300 watt m
500 watt m
8.50)
13.00
32. OOf
42.00J
4,336.51
1.29
Toronto
626,674
<
[ 46,327
3,090
67
1,408
153
5
364
391
68
{ 75
100 watt m
200 watt m
250 watt m
300 watt m
500 watt m
1 ,000 watt m
100 w. 5-lt. stds. m
300 w. 1-lt.stds. m
500 w. 1-lt.stds. m
500 w. 1-lt. stds. m
8.00-10.00'
18.00-23.00
20.00
28 . 00-30 . 00
45.00
90.00
47.50
50.00
47.50
52.50J
»
531,411.66
.85
Toronto Twp. . .
r 4ii
100 watt m
Intersection Lt.
12.001
43.00/
4,975.20
**
Tottenham ....
546
49
150 c.p. 5
25.00
1,225.08
2.24
Trenton
6,331
{ 49
{ 309
I 1
600 c.p. 5
100 watt m
500 watt m
75.00)
14.00
75. 00 J
8,076.00
1.28
Tweed
1,247
125
100 c.p. s
15.00
1,886.25
1.51
Uxbridge
1,506
f 129
1 I
100 watt m
100 w. Pk. Lts. m
200 watt m
13.00)
10.00
16.00J
1,743.00
1.16
**Population not shown in Government statistics. s Series system. m Multiple system.
tfPart cost paid direct in the form of debenture charges.
934
HYDRO-ELECTRIC POWER COMMISSION
403
STATEMENT "C"— Continued
Street Lighting Installation in Hydro Municipalities, December 31, 1933, showing
Rate per Lamp, Cost to Municipality per Annum, and Cost per Capita.
Number
Size and
Rate per
Total cost to
Cost
Municipality
Population
of
style of
lamp
municipality
per
lamps
lamps
per annum
per annum
capita
$ c.
$ c.
$ c.
Victoria Harbor
1,171
78
f 1
100 watt
. 75 c.p.
m
s
9.00
6.00)
702.00
.60
Walker ton
2,340
'
114
[ 38
150 c.p.
300 c.p.
s
s
12.50
24. 50 J
2,369.55
1.01
[ 33
600 c.p.
s
45.00^
138
100 watt
m
8.00
VValkerville. . . .
10,681
332
63
150 watt
200 watt
m
m
11.00
13.00
•
11,739.96
ft
110
300 watt
m
18.00,
•
f 186
150 c.p.
S
12.001
Wallaceburg . . .
4,343
12
[ 50
400 c.p.
5
22.00V
4,167.00
.96
300 watt
m
33. OOJ
Wardsville
214
35
75 watt
m
20.00
700.00
3.27
Wark worth. . . .
<
r 34
I 2
100 watt
200 watt
m
m
18.00\
30.00/
643 . 75
**
Waterdown ....
924
<
r 74
I 5
100 watt
200 watt
m
m
11.001
17.50/
901.50
.97
r 157
100 watt
m
8.001
Waterford .....
1,168
I I
' 339
120-
91
5
200 watt
500 watt
80 c.p.
100 c.p.
150 watt
200 watt
m
m
s
s
m
m
20.00
35.00,
8.00^
10.00
10.00
12.00
1,608.00
1.38
Waterloo
8,563
18
3
9
10
[ 44
300 watt
500 watt
500 watt
3-Lt. Stds.
5-Lt. Stds.
m
m
m
m
21.00
30.00
35.00
25.00
36.00J
7,499.04
.88
Watford
956
■
' 90
11
100 watt
200 watt
m
m
12.501
20.00/
1,344.96
1.41
Waubaushene. .
45
f 178
100 watt
400 c.p.
m
s
9.00
405.00
**
30.001
420
100 watt
m
11.00
Welland
10,668
■
30
200 watt
m
18.00
10,559.01
12
300 watt
m
30.00
tt
4
500 watt
m
28.00
Wellesley
,
60
46
32
100 watt
100 c.p.
150 c.p.
m
s
s
12.00
12.001
19.00/
720.00
1,160.04
**
Wellington ....
900
1.29
est Lome. . . .
814
' S3
{ io
100 watt
200 watt
m
m
10.001
18.00/
1,010.00
1.24
**Population not shown in Government statistics. s Series system.
ffPart cost paid direct in the form of debenture charges.
m Multiple system,
404
TWENTY-SIXTH ANNUAL REPORT OF THE
No. 26
STATEMENT "C"— Concluded
Street Lighting Installation in Hydro Municipalities, December 31, 1933, showing
Rate per Lamp, Cost to Municipality per Annum, and Cost per Capita.
Municipality
Population
Number
of
lamps
Size and
style of
lamps
Rate per
lamp
per annum
Total cost to
municipality
per annum
Weston
4,736
f 456
2
113
20
5
2
100 c.p.
250 c.p.
600 c.p.
300 watt
5-Lt. Stds.
Electric Sign
5
s
s
ryi
m
3 m
$ c.
7.50 N
10.00
30.00
11.00
21.00
110.00,
>
$ c.
7,610.13
$ c
1.61
West port
733
60
100 watt
m
28.00
1,705.00
2.33
W'heatley
724
f 62
I 37
100 watt
150 watt
m
m
12.00)
15.00/
1,355.25
1.87
f 126
80 c.p.
s
10.00)
Whitby
5,294
J 66
163
I 3
100 c.p.
100 watt
500 watt
s
m
m
11.00
8.50
12.50J
3,716.43
.7C
W'iarton
1,911
/ 100
\ 25
100 watt
200 watt
m
m
16.00)
28.00/
2,300.00
1.20
Williamsburg. . .
16
100 watt
m
12.00
192.00
**
Winchester ....
963
118
100 watt
m
9.00
1,062.00
1.10
Windermere. . .
135
13
100 watt
m
35.00
455.00
3.37
Windsor
65,565
■
2,902
11
976
703
66
100 c.p.
250 c.p.
400 c.p.
600 c.p.
1,000 c.p.
s
s
s
s
s
11.50)
17.50
27.50
36.00
46.00J
76,109.88
tt
W'ingham
1,842
' 101 .
25
22
100 c.p.
200 c.p.
200 watt
s
s
m
19.00)
32.00
32.00J
3,423.00
\M
Woodbridge. . .
744
90
100 watt
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